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Home My WebLink About210-1061. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Tubing Swap 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 10,594 NA Casing Collapse Conductor NA Surface 2,260psi Intermediate 4,760psi Prod Liner Slotted Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 4-1/2" x 9-5/8" AHR Retrievable Packer and NA 5,464' MD / 3,489' TVD and NA NA 10,5944,821 3,688 Operations Manager November 3, 2025 3-1/2" Perforation Depth MD (ft): See Schematic 160 20" 13-3/8" 9-5/8" 2,335 907-777-8503 ryan.rupert@hilcorp.com See Schematic 5,991 5,020psi 6,870psi 2,161 3,653 2,335 5,991 5-1/2" 160 160 L-80 TVD Burst 10,379 Slotted MD NA Hilcorp Alaska, LLC Length Size Proposed Pools: 3,688 10,594 3,688 647 SCHRADER BLUFF OIL SCHRADER BLUFF OIL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0355024, ADL0373301, ADL0390616, ADL0391283 210-106 NIKAITCHUQ OI11-01 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-23430-00-00 NIKAITCHUQ PRESENT WELL CONDITION SUMMARY AOGCC USE ONLY Tubing Grade: L-80 Tubing MD (ft): 5,737Perforation Depth TVD (ft): Ryan Rupert Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: 4-1/2" Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 9:43 am, Oct 20, 2025 Digitally signed by Sara Hannegan (2519) DN: cn=Sara Hannegan (2519) Date: 2025.10.17 15:23:08 - 08'00' Sara Hannegan (2519) 325-646 10-404 * BOPE pressure test to 2500 psi. 24 hour notice to AOGCC. * Variance approved to 20 AAC 25.412 (b) for packer to be set > 200' above top of perforations, as the packer will be within the SB injection zone. SFD 10/23/2025MGR28OCT25 DSR-10/30/25 10/31/25 Tubing Swap RWO Well: Oliktok Point OI11 Well Name:OI11 API Number:50-029-23430-00-00 Current Status:Offline water injector Permit to Drill Number:210-106 First Call Engineer:Ryan Rupert (907) 301-1736 (c) Second Call Engineer:Keith Lopez (907) 903-5432 (c) Maximum Expected BHP:1015 psi @3,688 TVD (5.3ppg) Downhole gauge (10/13/25) Max. Potential Surface Pressure: 647 psi Using 0.1 psi/ft Brief Well Summary OI11 is an offline water injector in the OA sands (Schrader Bluff). It failed its 4-year MIT-IA in summer-2023. The well passed a CMIT-TxIA, and several tubing leaks were identified. 5 total patches were set based on diagnostics. After the 5th and shallowest one was set on 8/12/23, the setting tool didnt release, and EL left the fish. SL fishing at the time was unsuccessful. An AA was applied for and granted. The well was put back on injection through the fish and injected until summer of 2025 when it was due for its biannual CMIT-TxIA. SL and CT tried to remove the fish to no avail. Being unable to set a deep plug and conduct a CMIT-TxIA, the well went non-operable 8/1/25, and has been shut in since. This procedure aims to fish / swap the tubing and restore integrity so we can return the well to water injection Pertinent History - July/August-2023: o CMIT-TxIA passed to 1500psi against cat standing valve in XN-nipple at 5480' below packer. o MIT-T passes above 2548 to 750psi o 4-1/2" x 2-7/8" nipple reducer set in XN nipple at 5480' MD o CMIT-TxIA to 1450psi PASSED against cat standing valve in nip reducer o Caliper and acoustic leak log: Set 2 deepest patches. MIT-IA FAILS. - August-2023 o Acoustic leak log #2. Set patches 3 / 4 / 5. Get stuck after setting patch #5 o EL pulled free and left setting tool fish in top patch at TOF = 3288' MD. o SL fishing unsuccessful o MIT-IA still fails with pressure losses of 200psi per 15mins o 9/13/23: AA received to operate well with TxIA. CMIT-TxIAs dues every 2 years - July-2025 o MIT-IA fails losing 200psi in 15 minutes o SL and CT fishing unsuccessful o CT spotted Safeacid, but still no success. CT parted rope socket - 7/31/25: o Last day of AA, well shut-in and made non-operable o Was injecting 5500bwpd at 655psi WHIP when shut in Tubing Swap RWO Well: Oliktok Point OI11 Pertinent wellbore information: - Max deviation above nipple reducer at 5480 MD: o 70 degree sail angle from 3300 5480 MD o Several successful SL and EL drifts down to 5480 MD (no tractor needed) - Min ID: o 2.205: 2-7/8 XN- nipple at 5480 MD o 2.992 drift ID through 5 permanent patches (once setting tool fish removed) - Wellbore fluids o Tubing has injection water down deep and diesel freeze protect down to at least 2200 MD o IA has diesel freeze protect down to at least 2200 MD and unknown below that o Lower IA has either >8.33ppg injection water, OR original 9.1ppg completion brine - Backside cables (qty = 2) o One for fiber optic and one for pressure sensor o Encapsulated ¼ lines: 0.43 x 0.43 square o No splices noted o Each connection should have a cross collar Polyoil clamp (NOT standard Cannon clamps see e- file):5.906 OD - Tubing details: 4-1/2 IBT-M o T&C connection o OD = 5.20 o Coupling length: 8.5 - Fish details o CT retrieved Overshot and broken rope socket 7/24/25, so ToF could be below 3288 MD. o 3.68 bait on top planted by SL (7/6/25). OAL = 31 o Top setting tool fishing neck: 3288 o Collar: 3295 o Top patch seal element: 3304 o Leak signature: 3318 3334 o Collar: 3338 o Bottom patch seal element: 3346 Hilcorp requests a variance to set our injection packer greater than 200 MD above top perf. -Shallowest injection sleeve (ICD) at 6283 MD / 3668 TVD -Old packer at 5464 MD / 3489 TVD (not planning on fishing out) -Proposed new packer location: 5300 MD / 3429 TVD -Top Schrader Bluff oil Pool: 5179 MD / 3386 TVD -ToC behind 9-5/8: 3725 MD / 2860 TVD (10/14/10 USIT) New packer location is still below top pool, >250 TVD below logged ToC, is close to existing packer, and still <250 TVD from top injection. Hilcorp requests a variance to set our injection packer greater than 200 MD above top perf. -Shallowest injection sleeve (ICD) at 6283 MD / 3668 TVD -Old packer at 5464 MD / 3489 TVD (not planning on fishing out) -Proposed new packer location: 5300 MD / 3429 TVD -Top Schrader Bluff oil Pool: 5179 MD / 3386 TVD -ToC behind 9-5/8: 3725 MD / 2860 TVD (10/14/10 USIT) Tubing Swap RWO Well: Oliktok Point OI11 Pre-rig procedure 1. MIRU EL and PT PCE to 1500 high / 250psi low 2. RIH to top fish and avoiding collars and cut just above TOF at 3,288 MD (2642 TVDss) 3. Pull jewelry log (CCL only) to surface (to tie-top fish in and give us an idea where bottom of fish may be) 4. RDMO EL RWO procedure 1. MIRU Nordic #4 2. Kill well: a. Work over fluid will be injection water (8.33ppg or heavier) b. Ensure any wellbore fluids are fully displaced with KWF either via circulation or bullheading c. Circulate tubing and IA to KWF through tubing punches:226bbls d. Bullhead tubing volume below punches to injection device at 6283 MD (3668 TVD) = 50bbls Likely unable to initially displace IA fluid below tubing cut. Should be either 8.33ppg injection water, or 9.1ppg completion brine, so well will remain overbalanced to formation, but tubing and IA may be out of balance until we can circulate from deep. 3. Set BPV/TWC, ND tree, NU BOP stack (see attached) a. Notify AOGCC 48 hours in advance for witness b. Test to 250psi Low /2,500psi High / 2,500psi Annular c. BOPE will be used as needed to circulate the well 4. Pull BPV/TWC 5. BOLDS and unseat tubing hanger 6. Pull tubing into tension, and if necessary RU EL 7. RIH with EL and cut tubing just above TOF at 3288 MD (if necessary) 8. POOH and RD EL 9. POOH with upper completion laying down 4-1/2 tubing and cap line from shallow EL cut 10. MU washpipe with external cutters 11. RIH on workstring and swallow 4-1/2 tubing with fish / patch in it 12. Perform external cut below bottom patch (3350 MD or deeper) 13. Pull cut joint of tubing with fish inside Different iterations of cutting / washing / milling may be needed to get a deep cut of the 4-1/2 tubing. TBD. Fishing operations will continue until we can cut at our target depth, per below Tubing Swap RWO Well: Oliktok Point OI11 14. RIH and overshot tubing stub 15. Pull tubing into tension, and RU EL 16. RIH with EL and cut tubing at ±5410 MD above existing injection packer a. Target just below a connection b. 5365: top full joint c. 5407: top full joint d. 5410: target cut here e. 5449: Top pup f. 5451: X-nipple g. 5452: top pup h. 5464: top Packer 17. Circulate / bullhead a WBV down through the deep cut a. IA volume from surface to deep cut: 292bbls b. Tubing volume from surface to deep cut: 83bbls 18. POOH with lower completion laying down 4-1/2 tubing and cap line from deep EL cut 19. MU 4-1/2 injection completion 20. RIH with stacker packer completion to include a non-sealing overshot below the packer 21. Land completion with new packer at ~5300 MD (3429 TVD) 22. Set packer and perform charted MIT-IA to 1500psi 23. Shear out GLV and freeze protect well 24. RDMO RWO crew and equipment Post-rig 1. MIRU SL and PT PCE to 1500 high / 250psi low 2. Pull B&R 3. Set DGLV 4. Pull catcher sub 5. RDMO SL 6. Bring well on injection 7. Within 30 days of stabilized injection,perform charted / AOGCC MIT-IA to 1500psi with well online injecting Attachments: 1. Current Wellbore Schematic 2. Proposed wellbore schematic 3. Nordic-4 BOPE diagram Nikaitchuq Field Last Completed: 10/16/2010 PTD: 210-106 API #: 50-029-23430-00-00 A Casing Hole MD 20160' 20" 1 5-1/2" 10,594' B Size ID Top Btm Btm TVD 13-3/8" 20 N/A Surface 160' 160' 13-3/8" 12.415" Surface 2,335' 2,161' 9-5/8"8.681" Surface 5,991' 3,653' 5-1/2" 4.892" 5,773' 10,594' 3,688' C 4-1/2" 3.958" Surface 5,737' 3,589' 3-1/2" 2.992" 5,737' 10,379' 3,688' D No. MD(ft) TVD(ft) Inc ID E A 39 39' 0 3.958" B 2,233 2,084' 40 3.813" C 3,304 2,702' 67 2.992" F D 3,531 2,789' 68 2.992" E 3,706 2,853' 68 2.992" F 4,543 3,158' 69 2.992" G G 5,140 3,373' 69 2.992" H 5,451 3,484' 68 3.813" I 5,464 3,489' 67 H J 5,480 3,495' 67 2.205" K 5,736 3,589' 72 2.992" I L 5,773 3,601' 73 M 5,745 3,592' 72 2.992" J St. MD (ft) TVD (ft) Inc Valve Latch Port 1 2,133 2,006 37 Dummy ? N/A K L 5-1/2" Slotted liner from 5,773' MD (3,601' TVD) to 10,594' MD (3,688' TVD) M 5-1/2" x 8-1/2" Swell Packers (x3) 9-5/8" 3-1/2" x 5-1/2" Swell Packers (x3) Injection Control Devices (x 12) Single 1/4" Stainless Steel Encapsulated Line with Double End DTS Fiber 3-1/2" Gauge Carrier HES "X" Nipple 4-1/2" x 9-5/8" AHR Retrievable Packer HES "XN" Nipple, and 2.205" Nipple reducer 4-1/2" x 3-1/2" Crossover 5-1/2" Liner Hanger Wt/ Grade/ ConnType Slotted Liner, Uncemented CASING DETAIL 9-5/8"12-1/4" hole, 211 bbls (774sx) 12.5 ppg LiteCrete, 3,725' MD USIT Log 10/14/10 6,007' 12.6#, L-80, IBT-M 9.2#, L-80, IBT-M UPPER COMPLETION EQUIPMENT 179#, LX-65, Welded 68#, L-80, BTC 47#, L-80, BTC-M 17#, L-80, Hyd 521 TUBING DETAIL Tubing Planted Non-releasable Bowen Overshot on top of EL Fish. 3.68" Bait Sub (3.12" ID x13" deep) 3.60" Bowen Body w/ 1-1/2" grapple. 31" OAL. EL Fish Owens Setting Tool OAL 58.98". Max OD 3.50" Fish LIH 12-AUG-23. Overshot Planted 6-July-25 Description Vacuum Insulated Tubing (VIT), 3 jts. ~102' long HES "X" Nipple OI11-01 Schematic Schrader Bluff Water Injector 13-3/8" 2,347' Driven, Uncemented 16" hole, 533 bbls 10.7 ppg Arctic Lite III Lead, plus 70 bbls 12.5 ppg LiteCrete tail. 200 bbls cement returned to surface. Cement Details CEMENT DETAIL Tubing Slotted Production Liner Intermediate Surface Conductor Tubing Patched Date Complete Oct 2010 Aug 2023 Event Drilled & Completed GAS LIFT MANDRELS 4-1/2" x 1" ? ? 7/7/23 TYPE KBMG Date 5th Tubing patch, 3,304' to 3,346' 4th Tubing patch, 3,531' to 3,552' 3rd Tubing patch, 3,706' to 3,738' 2nd Tubing patch, 4,543' to 4,585' 1st Tubing patch, 5,140' to 5,172' 70 degree inclination @ 4,658' MD (3,199' TVD) X Gauge X XN Encapsulated 0.43" x 0.43" square line XN OI11-01 Schematic 10-15-2025 Last edited by: GP 10/15/2025 Nikaitchuq Field Last Completed: 10/16/2010 PTD: 210-106 API #: 50-029-23430-00-00 Casing Hole MD 20160' 20" 1 5-1/2" 10,594' Size ID Top Btm Btm TVD 13-3/8" 20 N/A Surface 160' 160' 13-3/8" 12.415" Surface 2,335' 2,161' 9-5/8"8.681" Surface 5,991' 3,653' 5-1/2" 4.892" 5,773' 10,594' 3,688' 4-1/2" 3.958" Surface 5,410' 3,468' 4-1/2" 2.992" 5,410' 5,737' 3,589' 3-1/2" 2.992" 5,737' 10,379' 3,688' No. MD(ft) TVD(ft) Inc ID A 5,300 3,429' 69 3.958" B 5,375 3,456' 69 3.813" A C 5,451 3,484' 68 3.813" D 5,464 3,489' 67 B E 5,480 3,495' 67 2.205" F 5,736 3,589' 72 2.992" G 5,773 3,601' 73 H 5,745 3,592' 72 2.992" C D St. MD (ft) TVD (ft) Inc Valve Latch Port 1 2,200 2,060 39 TBD TBD TBD E F G 5-1/2" Slotted liner from 5,773' MD (3,601' TVD) to 10,594' MD (3,688' TVD) H 5-1/2" x 8-1/2" Swell Packers (x3) 9-5/8" 3-1/2" x 5-1/2" Swell Packers (x3) Injection Control Devices (x 12) Single 1/4" Stainless Steel Encapsulated Line with Double End DTS Fiber GAS LIFT MANDRELS 4-1/2" x 1" ? ? TBD TYPE TBD Date Tubing Patched Date Complete Oct 2010 Aug 2023 Event Drilled & Completed Description Packer HES "X" Nipple OI11-01 Proposed Schematic Schrader Bluff Water Injector 13-3/8" 2,347' Driven, Uncemented 16" hole, 533 bbls 10.7 ppg Arctic Lite III Lead, plus 70 bbls 12.5 ppg LiteCrete tail. 200 bbls cement returned to surface. Cement Details CEMENT DETAIL Tubing Slotted Production Liner Intermediate Surface Conductor 12.6#, L-80 12.6#, L-80, IBT-M UPPER COMPLETION EQUIPMENT 179#, LX-65, Welded 68#, L-80, BTC 47#, L-80, BTC-M 17#, L-80, Hyd 521 TUBING DETAIL Tubing Tubing 9.2#, L-80, IBT-M Wt/ Grade/ ConnType Slotted Liner, Uncemented CASING DETAIL 9-5/8"12-1/4" hole, 211 bbls (774sx) 12.5 ppg LiteCrete, 3,725' MD USIT Log 10/14/10 6,007' 3-1/2" Gauge Carrier HES "X" Nipple 4-1/2" x 9-5/8" AHR Retrievable Packer HES "XN" Nipple, and 2.205" Nipple reducer 4-1/2" x 3-1/2" Crossover 5-1/2" Liner Hanger 70 degree inclination @ 4,658' MD (3,199' TVD) X Gauge X XN Encapsulated 0.43" x 0.43" square line XN Proposed tubing cut @ 5,410' OI11-01 Proposed Schematic 10-15-2025 Last edited by: GP 10/15/2025 Nordic Rig 4 ARRS 5M Nordic Calista 02.24.2025 All Components 5,000 psi BLIND/SHEAR RAMS VBR RAMS CHOKE HCR MANUAL CHOKE KILL HCR INSIDE KILL3" 5,000 PSI WP KILL LINE Annular 2 7/8 x 5 VBR CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: Not Operable: OI11-01 (PTD# 2101060) Date:Thursday, July 31, 2025 11:33:28 AM From: Stephen Soroka <steve.soroka@hilcorp.com> Sent: Thursday, July 31, 2025 10:50 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Ryan Thompson <Ryan.Thompson@hilcorp.com> Subject: Not Operable: OI11-01 (PTD# 2101060) Mr. Wallace, OI11-01 is a PWI well that has been injecting under AIO 36.009 after passing a CMIT on 7/7/23. The well is due for a 2-year CMIT this month. Slickline and Coil Tubing were unsuccessful in fishing the patch setting tool LIH. Therefore, the CMIT will not be completed. The well is now being classified as Not Operable and will be shut in. Please respond with any questions. Thanks Steve Soroka Hilcorp Alaska LLC Field Well Integrity Steve.Soroka@hilcorp.com P: (907) 830-8976 Alt: Chris Casey The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. New Plugback Esets 7/15/2024 Well Name API Number PTD Number ESet Number Date CRU C1-07 PB2 50-103-20478-71-00 203-225 T39188 1-29-2007 CRU CD2-467 PB1 50-103-20579-70-00 208-114 T39189 10-31-2008 CRU CD4-12 PB1 50-103-20414-70-00 210-091 T39190 9-20-2010 CRU CD4-210A PB1 50-103-20533-70-00 211-072 T39191 9-9-2011 KRU 1B-15AL3 PB1 50-029-22465-72-00 207-067 T39192 11-23-2009 KRU 1E-12L1 PB1 50-029-20736-70-00 210-004 T39193 5-24-2010 KRU 1E-12L2-01 PB1 50-029-20736-72-00 210-007 T39194 5-24-2010 KRU 3H-12A PB1 50-103-20088-70-00 211-081 T39195 9-9-2012 KRU 3I-11AL2 PB1 50-029-21932-70-00 210-076 T39196 11-1-2010 ODSK-33 PB1 50-703-20562-70-00 207-183 T39197 6-20-2008 OI11-01 50-029-23430-70-00 210-106 T39198 11-2-2010 OP04-07 PB1 50-029-23409-70-00 208-199 T39200 7-6-2010 OP08-04 PB1 50-029-23424-70-00 210-041 T39201 7-28-2010 PBU 06-02A PB1 50-029-20282-70-00 211-026 T39202 7-25-2011 PBU 15-05B PB1 50-029-20731-71-00 211-057 T39203 8-20-2011 PBU 15-16B PB1 50-029-21115-70-00 210-020 T39204 7-8-2010 PBU 18-04B PB1 50-029-20875-70-00 201-090 T39205 12-6-2002 PBU J-16B PB1 50-029-20967-70-00 212-014 T39206 9-28-2012 PBU K-05D PB1 50-029-21418-71-00 211-077 T39207 1-20-2012 PBU V-204L1 50-029-23217-60-00 204-132 T39208 11-13-2006 PBU W-19B PB1 50-029-22006-72-00 210-065 T39209 1-13-2011 PBU W-19BL1 PB1 50-029-22006-73-00 210-066 T39210 1-18-1011 SP23-N03 PB1 50-629-23456-70-00 211-127 T39211 3-5-2012 TBU M-10 PB1 50-733-20588-70-00 209-154 T39212 4-23-2010 OI11-01 50-029-23430-70-00 210-106 T39198 11-2-2010 Eni US Operating Co, Inc WELL LOG/DATA TRANSMITTAL To: AůaƐŬa Oiů anĚ GaƐ ConƐerǀation CoŵŵiƐƐio 333 W. 7th Ave, Anchorage, AK 99501 September 15, 2023 Well:OI11-01 Sundry 323-369 PTD 210-106 LWD/MWD Logs PDF LAS DLIS Excel Mudlogs E-line logs 4-1/2" MF Caliper logs x x 4-1/2" ACX x x PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Edgar Pinzon Mail: edgar.pinzon@eni.com Eni US Operating Co, Inc. PTD: 210-106 T37997 Kayla Junke Digitally signed by Kayla Junke Date: 2023.09.15 13:49:53 -08'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: OI11-01 (PTD# 210-106) TxIA Communication Date:Thursday, August 24, 2023 9:28:46 AM Attachments:image001.png image002.png From: Lopez Keith <Keith.Lopez@eni.com> Sent: Thursday, August 24, 2023 9:01 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Hart David <David.Hart@eni.com>; Giraud Hector <Hector.Giraud@eni.com>; Lyden Dan <Dan.Lyden@eni.com>; Dexheimer Stephen <Stephen.Dexheimer@eni.com>; Morgan Michael <Mike.Morgan@eni.com>; Zuber Joshua <Joshua.Zuber@eni.com>; Burgess Larry <Larry.Burgess@eni.com>; Pitzalis Francesco <Francesco.Pitzalis@eni.com>; Brown Timothy <Timothy.Brown@eni.com>; Vaughan Alex <Alex.Vaughan@external.eni.com>; Gueco Chad <Chad.Gueco@external.eni.com>; Iannucci Giorgio <Giorgio.Iannucci@eni.com>; Lopez Keith <Keith.Lopez@eni.com> Subject: RE: OI11-01 (PTD# 210-106) TxIA Communication Mr. Wallace, We have conducted the diagnostics on the tubing by inner annulus pressure communication in OI-11. We found indications of 5 separate tubing leaks and set 5 patches across them. Unfortunately, we were unable to disengage the patch setting tool from patch #5 and to date have been unable to retrieve it. On 08/18/23, we brought the well on injection through the patch setting tool’s bypass ports to warm up the patch sealing elements and verify that we have fixed the communication. We conducted an internal MIT on the inner annulus yesterday that failed. Next, we will conduct a short injectivity test to determine if we can get adequate injection rates past the fish before requesting an Administrative Approval for the well. Please let me know if you have any questions, concerns, or would like further information. Thank you. Keith Lopez Senior Production Engineer Eni Petroleum, Alaska 3700 Centerpoint Drive, Suite 500 Anchorage, AK 99503 Direct 907-865-3316 Mobile 907-903-5432 Keith.Lopez@eni.com From: Lopez Keith <Keith.Lopez@eni.com> Sent: Thursday, June 29, 2023 12:48 PM To: chris.wallace@alaska.gov; Regg, James B (CED) <jim.regg@alaska.gov> Cc: Hart David <David.Hart@eni.com>; Giraud Hector <Hector.Giraud@eni.com>; Lyden Dan <Dan.Lyden@eni.com>; Dexheimer Stephen <Stephen.Dexheimer@eni.com>; Morgan Michael <Mike.Morgan@eni.com>; Zuber Joshua <Joshua.Zuber@eni.com>; Burgess Larry <Larry.Burgess@eni.com>; Pitzalis Francesco <Francesco.Pitzalis@eni.com>; Brown Timothy <Timothy.Brown@eni.com>; Vaughan Alex <Alex.Vaughan@external.eni.com>; Gueco Chad <Chad.Gueco@external.eni.com>; Iannucci Giorgio <Giorgio.Iannucci@eni.com>; Lopez Keith <Keith.Lopez@eni.com>; Zuber Joshua <Joshua.Zuber@eni.com>; Morgan Michael <Mike.Morgan@eni.com> Subject: OI11-01 (PTD# 210-106) TxIA Communication Mr. Wallace, Early this morning (06-29-23), ENI noticed a concern with tubing by inner annulus communication on OI11-01. The IA pressure increased from 33 psi to over 500 psi in a 2-hour period. Injection into the well was shut off and the tubing and IA pressure declined. Injection was reestablished and the IA pressure was bled off and immediately rebounded. The injector was shut in and will remain shut in until further diagnostics can be conducted with slickline/eline. OI11-01 passed its last state witnessed MIT on 03/21/21. Please let me know of any concerns or further data the AOGCC requires. Thank you. Keith Lopez Senior Production Engineer Eni Petroleum, Alaska 3700 Centerpoint Drive, Suite 500 Anchorage, AK 99503 Direct 907-865-3316 Mobile 907-903-5432 Keith.Lopez@eni.com ------------------------------------------------------------------------------------------------------------------------------------------------------------------- ----- Message for the recipient only, if received in error, please notify the sender and read http://www.eni.com/disclaimer/ 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Slickline___ Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number):8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 10,594 feet N/A feet true vertical 3,688 feet N/A feet Effective Depth measured 10,594 feet 5,464 feet true vertical 3,688 feet 3,489 feet Perforation depth Measured depth 6283'-10315' feet True Vertical depth 3649-3689 feet Tubing (size, grade, measured and true vertical depth)4.5"L-80 5456' 3488' Packers and SSSV (type, measured and true vertical depth)HES AHR 5464' 3489' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work:Schrader Bluff 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Giorgio Iannucci Digital Signature with Date:8/31/2023 Contact Name:Amjad Chaudhry Contact Email:amjad.chaudhry@eni.com Authorized Title:Contact Phone:907-865-3379 323-369 Sr Pet Eng: Slotted Sr Pet Geo:Sr Res Eng: WINJ WAG N/A Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Gas-Mcf MD 24 measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure N/A N/AN/A N/A 4385636 N/A 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) N/A ACX, Caliper data will be uploaded on the SFTP site 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: 355024, 373301, 390616, 391283 Nikaitchuq Schrader Bluff Oil Pool Eni US Operating Co. Inc. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 210-106 50-029-23430-00-00 3700 Centerpoint Drive, Ste. 500, Anchorage, AK 99503 3. Address: OI11-01 N/A Length 154' 2334' 154'Conductor Surface Intermediate 20" 13.375" Size 154' 9.625" Slotted N/A 5020 6870 measured TVD Production Liner 5991' 4787' Casing Structural 3649' 5.5" 5991' 10594'3688' Plugs Junk measured 2334'2183' Burst Collapse N/A 2270 4760 p k ft t Fra O s 6.A G L PG , _ Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov Giorgio Iannucci By Grace Christianson at 4:16 pm, Sep 01, 2023 DSR-9/1/23 RBDMS JBS 090823 13-3/8" 68 ppf Casing,2,234' MD, 2,183 TVD,40º Inc9-5/8" 43.5-47 ppfIntermediateCasing, 5,991' MD, 3,649' TVD, 81º Inc4-½” 12.6 ppfProduction Tubing5-½” 15.5 ppfProduction Liner, 10,594 MD, 3,688' TVD, 89ºInc3-1/2" 9.2 ppf Inner String,10,378' MD, 3689' TVD,91º Inc3-½” x 5-½” SwellPackersInjection Control DevicesAHR Retr. Packer with 2 Feed-Thrus, 5,464 ' MD, 3489 TVD, 67º IncSingle ¼” Stainless Steel Encapsulated Line with Double End DTS Fiber ConfidentialAV 8/18/2023OI11-01 Injector With Fiber/Electric MonitoringNikaitchuq Field – Oliktok Point PadSingle ¼” Stainless Steel Encapsulated Line for Heel P/T gauge2133' MD, 2005' TVD, 35º Inc - 4-½” x 1" KBMG GLM, with 2,000 psi A-to-T shear valve2232' MD, 2084' TVD, 40º Inc - 3.81" X-nipple for possible injection valve5,480' MD, 3495' TVD, 67 º Inc - 3.725" XN and HAL Mirage Plug with Auto-fill valve 5,450 MD, 3484' TVD, 67º Inc - 3.81" X-nipple VIT, 3 joints, 4-½” x 6", approx 102'Tubing PatchAugust 20235,745' MD, 3591' TVD, 72º Inc – Gauge Carrier - for P,T at Heel 5,773' MD, Top Of Liner5-½” x 8-½” SwellPackersOwensXͲSpanTubingPatch's:Drift2.992"5thTubingPatch:3304.13'Ͳ3345.87'4thTubingPatch:3530.63'Ͳ3552.37'3rdTubingPatch:3706.13'Ͳ3737.87'2ndTubingPatch:4543.26'Ͳ4585.00'1stTubingPatch:5140.26'Ͳ5172.00'Fish1:OwensXͲSpantubingpatchrunningtool:TopofFish:3288.14'Length:58.98'Fish2:DLretrievaltoolskirtbrokenpieceDimensions:0.23"x.487"x1.1"Location:floatingnearfish1 Well Name: OI11-01 OR Wellbore Name: OI11-01 Well Code: 25056 Job: RIGLESS WCEI Level: N/A Daily Report Date: 7/5/2023 Report #: 1 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code WATER INJECTION WELL Rotary Table Elevation (ft) 53.25 Ground Level (ft) 12.20 First Flange (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) Rig Information Rig Name Contractor Rig Type Rig Num Daily Information Weather Clear Temperature (°F) 55.0 Wind SW @ 10 MPH Days LTI (days) 2,127.00 Days RI (days) POB 10.0 Daily Summary Operations 24h Forecast Perform 250 bbl diesel flush down tubing. Re-run 3.79" GR to XN-Nipple at 8450'. Run in the hole and set 4.5" Cat Standing Valve in XN-Nipple at 8450'. Pressure test tubing to determine leak detection. 24h Summary Move in and spot Halliburton Slick Line equipment, Worley crane and LRS pump truck. Held Safety Stand Down meeting with all contractors associated with the rigless work for the OI11. Pressure test lubricator to 2000 psi for 10 minutes. Run in the hole with BHA #1 as follows: 1.750" RS, 1.750 QC, 2-1/8" x 5' RS, 1.750" QC, 2-1/8" x 13' RS, 1.750" QC, 1.750" x 3' Oil Jars, 1.750" QC, 1.875" x 8' Spangs, 1.750" QC & 3.79" GR (OAL Tool Length = 32.9'). Stack out at 2133' (GLM), worked tool string and continued in the hole to 2232' (X-Nipple) and stack out, continue to work tool string slowly from 2400' - 8450' (XN-Nipple) while pushing debris down hole. Pulled out of hole with BHA #1. Rig down lubricator. Shut well in and secured wellhead. Operation at 07.00 Diesel flush tubing volume 250 bbl. Prepare to re-run 3.79" GR to the XN-Nipple at 8450'. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 06:00 6.00 6.00 PROD- MAN R 1 P No operations at this time. 06:00 11:30 5.50 11.50 PROD- MAN R 2 P Move in and spot Halliburton Slick Line equipment, Worley crane and LRS pump truck. 11:30 13:00 1.50 13.00 PROD- MAN R 1 P Held Safety Stand Down meeting with all contractors associated with the rigless work for the OI11 and management team. Following SSD and a lift plan meeting for upcoming lift of Slick Line equipment. 13:00 17:30 4.50 17.50 PROD- MAN R 2 P Rig up all equipment. Function test and verify all Slick Line equipment and controls working properly. 17:30 19:00 1.50 19.00 PROD- MAN R 12 P Stab on well. Attempt to pressure test lubricator. Trouble shoot LRS equipment and found 2 bad check valves. Replaced check valves and resumed pressure test. Pressure test lubricator to 2000 psi for 10 minutes. Test good. Released pressure. 19:00 22:00 3.00 22.00 PROD- MAN R 4 P Run in the hole with BHA #1 as follows: 1.750" RS, 1.750 QC, 2-1/8" x 5' RS, 1.750" QC, 2-1/8" x 13' RS, 1.750" QC, 1.750" x 3' Oil Jars, 1.750" QC, 1.875" x 8' Spangs, 1.750" QC & 3.79" GR (OAL Tool Length = 32.9'). Stack out at 2133' (GLM), worked tool string and continued in the hole to 2232' (X-Nipple) and stack out, continue to work tool string slowly from 2400' - 8450' (XN-Nipple) while pushing debris down hole. Pulled out of hole with BHA #1. Rig down lubricator. Shut well in and secured wellhead. Shut down for the night. 22:00 00:00 2.00 24.00 PROD- MAN R 1 P No operations at this time. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Jody Cornell ASRC Energy Services Co. Man jody.cornell@external.eni.com 907-685-0710 Eni representative Yelyzaveta Saprykina ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.95 L80 -3,848.4 10,594.0 3,687.6 10/12/2010 Well Name: OI11-01 OR Wellbore Name: OI11-01 Well Code: 25056 Job: RIGLESS WCEI Level: N/A Daily Report Date: 7/6/2023 Report #: 2 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code WATER INJECTION WELL Rotary Table Elevation (ft) 53.25 Ground Level (ft) 12.20 First Flange (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) Rig Information Rig Name Contractor Rig Type Rig Num Daily Information Weather Clear Temperature (°F) 54.9 Wind Calm Days LTI (days) 2,128.00 Days RI (days) POB 10.0 Daily Summary Operations 24h Forecast Perform MIT-Tubing test. Contingency is to replace bad shear valve causing communication or switch over to E-line to perform ACX leak detection log pending results of the morning operations. 24h Summary Pumped a total of 250 bbl tubing flush. Run in the hole with 3.79" GR to 5840' (XN-Nipple) and no restrictions. Pull out of the hole. Make up BHA #2. Run in the hole to 8540' and set 4.5" Cat Standing Valve in XN- Nipple. Shear off and pull out of the hole. Pump 41 bbls of water to catch pressure on tubing. Pressured up to 500 psi and bleed down rapidly several times. Pump 17 bbls of diesel down the IA to fluid pack leaving 40 psi on IA. Pressure up tubing to 500 psi with good communication between tubing and IA annulus. Make up BHA #3. Run in the hole to 2133' with kick out tool. Latch and remove shear valve from GLM #1. Pull out of hole. Shut well in. Secure wellhead. Shut down for the night. Operation at 07.00 Run in the hole and set 1" dummy valve in GLM #1. Perform MIT-Tubing test. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 06:00 6.00 6.00 PROD- MAN R 1 P No operations at this time. 06:00 09:00 3.00 9.00 PROD- MAN R 9 P PJSM. Lined up well and had production department pump 58 bbls diesel flush and swapped over to injection water for an additional 192 bbls down tubing with average injection rate of 3 BPM & 220 psi. 250 bbls total tubing flush volume. 09:00 11:30 2.50 11.50 PROD- MAN R 15 P Stab lubricator on well. Pressure test lubricator. Run in hole with BHA #1 as follows: 1.750" RS, 1.750 QC, 2-1/8" x 5' RS, 1.750" QC, 2-1/8" x 13' RS, 1.750" QC, 1.750" x 3' Oil Jars, 1.750" QC, 1.875" x 8' Spangs, 1.750" QC & 3.79" GR (OAL Tool Length = 32.9'). No tight spots or debris found, tag XN-Nipple at 5480'. Pull out of hole with 3.79" GR. 11:30 13:45 2.25 13.75 PROD- MAN R 12 U Make up BHA #2. Stab on well with lubricator. Attempt to pressure test lubricator. Trouble shoot and found missing O-ring on the Otis connection. Nipple down lubricator, BOP and upper swab to recover O-ring. Install new O-ring. Stab on well. Pressure test lubricator. Test good. 13:45 16:00 2.25 16.00 PROD- MAN R 15 P Run in hole with BHA #2 as follows: 1.750" RS, 1.750 QC, 2-1/8" x 5' RS, 1.750" QC, 2-1/8" x 13' RS, 1.750" QC, 1.750" x 3' Oil Jars, 1.750" QC, 1.875" x 8' Spangs, 1.750" QC, 4.5" GS & 4.5" Cat Standing Valve pinned with 1/8" brass half pin (OAL Tool Length = 36.6'). Shear off Cat standing valve in the XN-Nipple at 5480'. Pull out of hole with Slick Line. 16:00 20:15 4.25 20.25 PROD- MAN R 9 P Lined up production to pump down tubing. Pumped 41 bbls of water down tubing and caught pressure. Pressured up tubing to 458 psi. Pressure loss down to -10 psi in less than 1 minute. Made several attempts to pressure test tubing with the same results. Discussed with town and decision was made to fluid pack the IA. Pumped 17 bbls of diesel down the IA and caught pressure. Pumped 1 bbl of water down tubing and pressured up to 500 psi. Tubing pressure decreased from 500 psi to 130 psi. IA increased from 40 psi to 330 psi (Good communication between tubing and IA). Discussed with town and decision was made to pull shear valve from GLM and allow the well to equalize overnight. 20:15 21:00 0.75 21.00 PROD- MAN R 5 P Make up BHA #3 (Kick over tool). Stab on well. Pressure test lubricator. Test good. 21:00 22:30 1.50 22.50 PROD- MAN R 15 P Run in hole with BHA #3 as follows: 1.750" RS, 1.750 QC, 2-1/8" x 5' RS, 1.750" QC, 2-1/8" x 13' RS, 1.750" QC, 1.750" x 3' Oil Jars, 1.750" QC, 1.875" x 8' Spangs, 1.750" QC & 4.5" ok-6 kick out tool. Locate and latch shear valve at 2133' and pull from GLM #1. Pull out of hole with Slick Line. Note: no shear valve was in the GLM, instead it is a 1" dummy valve. Tubing and annulus is not equalized, current pressures - tubing 84 psi, Annulus 220 psi (possible debris inside GLM #1). Rig down lubricator. Shut well in. Secure wellhead. Shut down for the night. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Jody Cornell ASRC Energy Services Co. Man jody.cornell@external.eni.com 907-685-0710 Eni representative Yelyzaveta Saprykina ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.95 L80 -3,848.4 10,594.0 3,687.6 10/12/2010 Well Name: OI11-01 OR Wellbore Name: OI11-01 Well Code: 25056 Job: RIGLESS WCEI Level: N/A Daily Report Date: 7/7/2023 Report #: 3 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code WATER INJECTION WELL Rotary Table Elevation (ft) 53.25 Ground Level (ft) 12.20 First Flange (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) Rig Information Rig Name Contractor Rig Type Rig Num Daily Information Weather Overcast Temperature (°F) 46.0 Wind E @ 25 MPH Days LTI (days) 2,129.00 Days RI (days) POB 10.0 Daily Summary Operations 24h Forecast Redress D&D Hole Finder. Run in the hole and continue with leak detection. 24h Summary Check pressures. Tubing -9 psi. A-Annulus 125 psi. Pressure up A Annulus to 300 psi and tubing pressure increased to 165 psi. Make up BHA #4. Run in hole. Set DV in GLM #1 at 2133'. Pull out of hole with SL. Perform Combo MIT test. Successful test. Make up BHA #5. Run in the hole. Unable to pass through 2800'. Sheared pin on the hole finder. Set D&D at 2795'. Test tubing to 500 psi with good communication on the annulus. Release plug and set at 2295'. Pressure test to 500 psi. Good test with 9 psi pressure gain on the annulus (expansion). Pull out of the hole to re-pin the D&D Hole Finder. Operation at 07.00 Redress D&D Hole Finder. Run in the hole and continue with leak detection. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 06:00 6.00 6.00 PROD- MAN R 1 P No operations at this time. 06:00 07:30 1.50 7.50 PROD- MAN R 1 P PJSM. Check pressures. Tubing -9 psi. A-Annulus 125 psi. Pressure up annulus with 0.5 bbls diesel to 300 psi and tubing pressure increased to 165 psi. 07:30 09:30 2.00 9.50 PROD- MAN R 15 P Make up BHA #4. Stab on well. Pressure test lubricator. Test good. Run in hole as follows: 1.750" RS, 1.750 QC, 2-1/8" x 5' RS, 1.750" QC, 2-1/8" x 13' RS, 1.750" QC, 1.750" x 3' Oil Jars, 1.750" QC, 1.875" x 8' Spangs, 1.750" QC & 4.5" ok-6 kick out tool with 1" dummy valve. Set DV in GLM #1 at 2133'. Pull out of hole with Slick Line. 09:30 10:30 1.00 10.50 PROD- MAN R 1 P Pressure up tubing to 500 psi. Clear communication from tubing to annulus. After 5 minutes tubing pressure is at 445 psi and A Annulus is at 500 psi. Line up to pump down annulus for a 30 minute combo MIT test. 10:30 12:30 2.00 12.50 PROD- MAN R 12 P Perform Combo MIT test. Pump 1.9 bbls LVT and pressure up A-Annulus to 1668 psi, tubing pressure at 1540 psi and OA at 170 psi. 15 minutes as follows: IA- 1623 psi, tubing - 1498 psi, OA- 170 psi. 30 minutes as follows: IA - 1612 psi, tubing - 1488 psi. OA - 170 psi. Successful test. 12:30 16:30 4.00 16.50 PROD- MAN R 15 P Make up BHA #5. Stab on well. Pressure test lubricator. Test good. Run in the hole as follows: 1.750" RS, 1.750 QC, 2-1/8" x 5' RS, 1.750" QC, 2-1/8" x 10' RS, 1.750" QC, 1.750" x 3' Oil Jars, 1.750" QC, 1.875" x 8' Spangs, 1.750" QC, 2.650" RB & 4.5" D&D Hole Finder. Unable to pass through 2800'. Sheared pin on the hole finder. Set D&D at 2795'. Test tubing to 500 psi with good communication on the annulus. Release plug and set at 2295'. Pressure test to 500 psi. Good test with 9 psi pressure gain on the annulus (expansion). Pull out of the hole to re-pin the D&D Hole Finder. 16:30 20:30 4.00 20.50 PROD- MAN R 15 P Redress D&D Hole Finder. Stab on well. Pressure test lubricator. Test good. Run in hole to 2800' & stack out. Worked down to 2900'. Pull up hole to 2695' and set plug. Attempt to pressure test tubing with good communication to the Annulus. Repeated same step every 100' to 2195' (100' above previous successful test). Unable to get plug to seal. HES recommended to pull out of the hole and inspect plug. LD toolstring and lubricator. Shut well in and secure wellhead. 20:30 00:00 3.50 24.00 PROD- MAN R 1 P No operations at this time. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Jody Cornell ASRC Energy Services Co. Man jody.cornell@external.eni.com 907-685-0710 Eni representative Yelyzaveta Saprykina ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.95 L80 -3,848.4 10,594.0 3,687.6 10/12/2010 Well Name: OI11-01 OR Wellbore Name: OI11-01 Well Code: 25056 Job: RIGLESS WCEI Level: N/A Daily Report Date: 7/8/2023 Report #: 4 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code WATER INJECTION WELL Rotary Table Elevation (ft) 53.25 Ground Level (ft) 12.20 First Flange (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) Rig Information Rig Name Contractor Rig Type Rig Num Daily Information Weather Overcast Temperature (°F) 37.6 Wind NE @ 16 MPH Days LTI (days) 2,130.00 Days RI (days) POB 10.0 Daily Summary Operations 24h Forecast MIRU Halliburton E-Line Equipment. Prepare to run 40 arm Caliper log followed by ACX leak detection log. 24h Summary Redress D&D Hole finder tool. Run in the hole with 4.5" D&D Hole Finder. Run in the hole and set plug at 2652'. Pressure up tubing to 500 psi for 5 minutes. Annulus pressure increased 30 psi (slow leak). Pull up hole to 2548' and set plug. Pressure up tubing to 500 psi for 5 minutes and no communication on the Annulus. Increased tubing pressure to 800 psi for 15 minutes and no pressure increase on Annulus. Hole in tubing is between 2552' - 2548'. Run in the hole and release 4.5" Cat Standing Valve. Operation at 07.00 Prepare to MIRU Halliburton E-line equipment. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 06:00 6.00 6.00 PROD- MAN R 1 P No operations at this time. 06:00 08:30 2.50 8.50 PROD- MAN R 15 P PJSM. Redress D&D Hole finder tool. Stab on well. PT lubricator. Test good. Run in the hole as follows: 1.750" RS, 1.750 QC, 2-1/8" x 5' RS, 1.750" QC, 2-1/8" x 10' RS, 1.750" QC, 1.750" x 3' Oil Jars, 1.750" QC, 1.875" x 8' Spangs, 1.750" QC, 2.650" RB & 4.5" D&D Hole Finder. Attempted to work tool through GLM #1 at 2133' & sheared the set pin. Pulled up hole to 2065'. Pressure up tubing to 500 psi and no communication on the Annulus. Pull out of hole to replace shear pin. 08:30 11:00 2.50 11.00 PROD- MAN R 15 P Replaced shear pin on the D&D Hole Finder tool. Stab on well. Pressure test lubricator. Test good. Run in the hole as follows; 1.750" RS, 1.750 QC, 2-1/8" x 5' RS, 1.750" QC, 2-1/8" x 10' RS, 1.750" QC, 1.750" x 3' Oil Jars, 1.750" QC, 1.875" x 8' Spangs, 1.750" QC, 2.650" RB & 4.5" D&D Hole Finder. Set plug at 2652'. Pressure up tubing to 500 psi for 5 minutes. Annulus pressure increased 30 psi (slow leak). Pull up hole to 2548' and set plug. Pressure up tubing to 500 psi for 5 minutes and no communication on the Annulus. Increased tubing pressure to 800 psi for 15 minutes and no pressure increase on Annulus. Good test. Hole in tubing is between 2552' - 2548'. Pull out of hole and lay down tool string. 11:00 13:30 2.50 13.50 PROD- MAN R 15 P Run in hole with BHA #6 as follows: 1.750" RS, 1.750 QC, 2-1/8" x 5' RS, 1.750" QC, 2-1/8" x 13' RS, 1.750" QC, 1.750" x 3' Oil Jars, 1.750" QC, 1.875" x 8' Spangs, 1.750" QC, 4.5" GR. Latch and release 4.5" Cat Standing valve at 5480'. Pull out of the hole and lay down tool string. Shut well in. Secure wellhead. 13:30 15:00 1.50 15.00 PROD- MAN R 2 P RDMO Halliburton slick line equipment. 15:00 00:00 9.00 24.00 PROD- MAN R 1 P No operations at this time. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Jody Cornell ASRC Energy Services Co. Man jody.cornell@external.eni.com 907-685-0710 Eni representative Yelyzaveta Saprykina ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.95 L80 -3,848.4 10,594.0 3,687.6 10/12/2010 Well Name: OI11-01 OR Wellbore Name: OI11-01 Well Code: 25056 Job: RIGLESS WCEI Level: N/A Daily Report Date: 7/9/2023 Report #: 5 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code WATER INJECTION WELL Rotary Table Elevation (ft) 53.25 Ground Level (ft) 12.20 First Flange (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) Rig Information Rig Name Contractor Rig Type Rig Num Daily Information Weather Overcast Temperature (°F) 41.7 Wind W @ 7 MPH Days LTI (days) 2,131.00 Days RI (days) POB 10.0 Daily Summary Operations 24h Forecast Repair caliper logging tools. Re-run caliper log from 5480' to surface. Send log information for analysis and prepare to run ACX log. 24h Summary MIRU Halliburton logging equipment. Assemble lubricator. Test and verify each function of the hydraulic system per color code chart on the unit. Make up BHA #1. Test Electronics on caliper. Pressure test lubricator to 2000 psi for 10 minutes. Run in the hole with 40 arm caliper tools to 5480' (XN-Nipple). Log from 5480' to surface. A malfunction in the telemetry section of the caliper was causing extreme noise and interference. Halliburton representative explained the log can not be processed and will need to be re-run following tool repairs. Operation at 07.00 Assemble new tool string, test and perform 40 arm caliper re-run. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 12:30 12.50 12.50 PROD- MAN R 1 P No operations at this time. 12:30 16:30 4.00 16.50 PROD- MAN R 1 P PJSM. Halliburton E-line equipment arrived on location. MIRU Halliburton logging equipment. Assemble lubricator. Test and verify each function of the hydraulic system per color code chart on the unit. 16:30 18:00 1.50 18.00 PROD- MAN R 12 P Make up BHA #1. Test Electronics on caliper. Stab on well. Pressure test lubricator to 2000 psi for 10 minutes. Test good. 18:00 22:15 4.25 22.25 PROD- MAN R 15 U Run in the hole as follows: 1.44" Cable Head, 1.69" swivel, 1-11/16" roller (2" Wheels), 1-11/16" x 7' weight bar, 1-11/16" roller (2" wheels), 1.69" x 7.65' Through Tubing Telemetry Cartridge, adapter, knuckle joint, collar locator, knuckle joint, 4 arm production roller centraliser, multifinger imaging tool, 4 arm production roller centraliser & SNDX TERM SR. Run in the hole to 5480' (XN-Nipple). Run 40 arm caliper log from 5480' to surface. A malfunction in the telemetry section of the caliper was causing extreme noise and interference. Halliburton representative explained the log can not be processed and will need to be re-run following tool repairs. 22:15 23:00 0.75 23.00 PROD- MAN R 1 P Lay down tool string and lubricator. Inspect tools with no visual issues found. Shut well in and secure wellhead. Shut down for the night. 23:00 00:00 1.00 24.00 PROD- MAN R 1 P No operations at this time. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Jody Cornell ASRC Energy Services Co. Man jody.cornell@external.eni.com 907-685-0710 Eni representative Yelyzaveta Saprykina ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.95 L80 -3,848.4 10,594.0 3,687.6 10/12/2010 Well Name: OI11-01 OR Wellbore Name: OI11-01 Well Code: 25056 Job: RIGLESS WCEI Level: N/A Daily Report Date: 7/10/2023 Report #: 6 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code WATER INJECTION WELL Rotary Table Elevation (ft) 53.25 Ground Level (ft) 12.20 First Flange (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) Rig Information Rig Name Contractor Rig Type Rig Num Daily Information Weather Overcast Temperature (°F) 41.2 Wind NE @ 13 MPH Days LTI (days) 2,132.00 Days RI (days) POB 19.0 Daily Summary Operations 24h Forecast Perform ACX log with recommended depths. Prepare for upcoming patch work to repair tubing leak. 24h Summary Pump 250 bbl water flush down tubing. Shut down pumps - tubing and Annulus are on a -13 psi vacuum. Make up 40 arm Caliper BHA. Stab on well. Pressure test lubricator. Run in hole to 500' and calibrate caliper. Tool is still showing interference. Trouble shoot and unable to repair in the hole. Pull out of hole. Change out the QPC section of the tools string. Make up 40 arm Caliper BHA. Run in hole to 500' and calibrate caliper. Continue to run in the hole to 5480' (XN-Nipple). Engage caliper and log from 5480' to surface. Lay down tool string and lubricator. Download data from caliper log and send for analysis. Operation at 07.00 Prepare to run ACX log with recommended depths. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 06:30 6.50 6.50 PROD- MAN R 1 P No operations at this time. 06:30 08:00 1.50 8.00 PROD- MAN R 1 P PJSM. Clean and disassemble caliper tools from previous run. 08:00 09:45 1.75 9.75 PROD- MAN R 9 P Opened up the well and pump 250 bbl water flush down tubing at 3.2 BPM with 220 psi. Shut down pumps and both tubing and Annulus are on a -13 psi vacuum. 09:45 12:30 2.75 12.50 PROD- MAN R 15 U Make up 40 arm Caliper BHA. Stab on well. Pressure test lubricator. Test good. Run in hole to 500' and calibrate caliper. Tool is still showing interference. Trouble shoot and unable to repair in the hole. Pull out of hole. Lay down tool string. Change out the QPC section of the tools string which operates pressure and temperature which is presumably to be the problem. 12:30 17:00 4.50 17.00 PROD- MAN R 15 P Make up 40 arm Caliper BHA. Stab on well. Pressure test lubricator. Test good. Run in hole to 500' and calibrate caliper. Log looks good. Continue to run in the hole to 5480' (XN-Nipple). Engage caliper and log from 5480' to surface. Lay down tool string and lubricator. Shut in well. Secure wellhead. Download data from caliper log and send for analysis. Shut down for the night. 17:00 00:00 7.00 24.00 PROD- MAN R 1 P No operations at this time. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Jody Cornell ASRC Energy Services Co. Man jody.cornell@external.eni.com 907-685-0710 Eni representative Yelyzaveta Saprykina ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Erik Bohlen ASRC Energy Services HSE Eric.Bohlen@external.eni.com 970-685-1434 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.95 L80 -3,848.4 10,594.0 3,687.6 10/12/2010 Well Name: OI11-01 OR Wellbore Name: OI11-01 Well Code: 25056 Job: RIGLESS WCEI Level: N/A Daily Report Date: 7/11/2023 Report #: 7 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code WATER INJECTION WELL Rotary Table Elevation (ft) 53.25 Ground Level (ft) 12.20 First Flange (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) Rig Information Rig Name Contractor Rig Type Rig Num Daily Information Weather Overcast Temperature (°F) 45.0 Wind W @ 3 MPH Days LTI (days) 2,133.00 Days RI (days) POB 19.0 Daily Summary Operations 24h Forecast Rig down E-line equipment. Rig up Slick line equipment. Prepare to perform a brush and flush on the production tubing followed by setting a 4.5" x 2-7/8" reducer nipple. Set 2-7/8" Cat Standing Valve inside nipple reducer and perform combo MIT Test. 24h Summary Make up test ACX BHA. Halliburton is having telemetry issues with the ACX tool. Trouble shoot and make repairs. Stab on well. Pressure test lubricator. Run in hole with ACX tool string. Made it to 2200' and had some missing data on the log. Pull up hole to 500' and made repairs. Continue in the hole to 5480' (XN-Nipple). Start injection with water down the Annulus maintaining 300 psi. Engage ACX tool and log from 5480' - 1900'. Pull out of the hole. Operation at 07.00 Rig down E-line equipment. Rig up Slick line equipment. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 06:00 6.00 6.00 PROD- MAN R 1 P No operations at this time. 06:00 13:00 7.00 13.00 PROD- MAN R 25 U PJSM. Make up test ACX BHA. Halliburton is having telemetry issues with the ACX tool. Trouble shoot and make repairs. 13:00 21:00 8.00 21.00 PROD- MAN R 15 P Stab on well. Pressure test lubricator. Test good. Run in hole with ACX tool string. Made it to 2200' and had some missing data on the log. Pull up hole to 500' and made repairs. Continue in the hole to 5480' (XN-Nipple). Start injection with water down the Annulus maintaining 200 psi. Engage ACX tool and log from 5480' - 1900'. Pull out of the hole. Lay down tool string and lubricator. Shut well in. Secure wellhead. Shut down for the night. 21:00 00:00 3.00 24.00 PROD- MAN R 1 U No operations at this time. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Jody Cornell ASRC Energy Services Co. Man jody.cornell@external.eni.com 907-685-0710 Eni representative Yelyzaveta Saprykina ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Erik Bohlen ASRC Energy Services HSE Eric.Bohlen@external.eni.com 970-685-1434 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.95 L80 -3,848.4 10,594.0 3,687.6 10/12/2010 Well Name: OI11-01 OR Wellbore Name: OI11-01 Well Code: 25056 Job: RIGLESS WCEI Level: N/A Daily Report Date: 7/12/2023 Report #: 8 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code WATER INJECTION WELL Rotary Table Elevation (ft) 53.25 Ground Level (ft) 12.20 First Flange (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) Rig Information Rig Name Contractor Rig Type Rig Num Daily Information Weather Overcast Temperature (°F) 38.3 Wind N @ 7 MPH Days LTI (days) 2,134.00 Days RI (days) POB 21.0 Daily Summary Operations 24h Forecast Run in the hole with 2-7/8" Cat Standing valve in nipple reducer. Perform combo MIT test. Remove Cat Standing Valve. RDMO Slickline. MIRU E-line. 24h Summary Rig down E-Line equipment. MIRU Slickline equipment. Make up Brush and Flush BHA. Stab on well. Open well up. Start injection water down tubing. Run in the hole to 2800'. Clean from 2800' - 2900' (6 passes). Continue in the hole to 4504' and make 6 passes to 4624'(4564' HIT). Continue in the hole to 5100'' and make 6 passes to 5220' (5160' HIT). Continue in the hole to 5480' (XN-Nipple), make 12 passes and brush the XN clean. Run in hole and set 4-1/2" x 2-7/8" Nipple Reducer at 5480' (XN-Nipple). Operation at 07.00 Run in the hole with 2-7/8" Cat Standing valve and set in nipple reducer for MIT combo test. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 06:00 6.00 6.00 PROD- MAN R 1 P No operations at this time. 06:00 08:30 2.50 8.50 PROD- MAN R 1 P PJSM. Rig down E-Line equipment. MIRU Slickline equipment. 08:30 13:00 4.50 13.00 PROD- MAN R 15 P Make up Brush and Flush BHA. Stab on well. Pressure test lubricator to 2000 psi for 10 minutes. Test good. Open well up. Start injection water down tubing at 2.2 BPM. Run in the hole as follows: 1.875" x 5' RS, QC, 1.875" x 5' RLR Stem with 2.6 wheels, 1.875" x 3' RLR Stem with 2.6 wheels, QC, KJ, QC, 1.875" x 3' RLR Stem with 2.6 wheels, QC, 1.750 Oil Jars, QC, KJ, 1.875" Spangs, QC & 4.5" Wire Brush. Run down to 2800'. Clean from 2800' - 2900' (6 passes). Continue in the hole to 4504' and make 6 passes to 4624'(4564' HIT). Continue in the hole to 5100'' and make 6 passes to 5220' (5160' HIT). Continue in the hole to 5480' (XN-Nipple), make 12 passes and brush the XN clean. Shut down pump. Pull out of the hole. Lay down tool string. 13:00 14:30 1.50 14.50 PROD- MAN R 5 P Make up 4-1/2" x 2-7/8" Nipple Reducer. Stab on well. Pressure test lubricator. Good test. 14:30 18:30 4.00 18.50 PROD- MAN R 15 P Run in hole as follows: 1.875" x 5' RS, QC, 1.875" x 5' RLR Stem with 2.6 wheels, 1.875" x 3' RLR Stem with 2.6 wheels, QC, KJ, QC, 1.875" x 3' RLR Stem with 2.6 wheels, QC, 1.750 Oil Jars, QC, KJ, 1.875" Spangs, QC and 4-1/2" x 2-7/8" Nipple Reducer. Set reducer in the XN-Nipple at 5480'. Pull out of hole. Shut well in. Secure wellhead. Shut down for the night. 18:30 00:00 5.50 24.00 PROD- MAN R 1 P No operations at this time. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Jody Cornell ASRC Energy Services Co. Man jody.cornell@external.eni.com 907-685-0710 Eni representative Yelyzaveta Saprykina ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Erik Bohlen ASRC Energy Services HSE Eric.Bohlen@external.eni.com 970-685-1434 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.95 L80 -3,848.4 10,594.0 3,687.6 10/12/2010 Well Name: OI11-01 OR Wellbore Name: OI11-01 Well Code: 25056 Job: RIGLESS WCEI Level: N/A Daily Report Date: 7/13/2023 Report #: 9 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code WATER INJECTION WELL Rotary Table Elevation (ft) 53.25 Ground Level (ft) 12.20 First Flange (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) Rig Information Rig Name Contractor Rig Type Rig Num Daily Information Weather Clear Temperature (°F) 44.0 Wind N @ 5 MPH Days LTI (days) 2,135.00 Days RI (days) POB 21.0 Daily Summary Operations 24h Forecast Begin patch running operations. Run in the hole and set tubing patches. 24h Summary Make up 2-7/8" Cat Standing Valve BHA. Run in the hole. Set CSV at 5480'. Lined up wellhead valves for production department to load the tubing and annulus with injection water. Used 105 bbls to fill the well. Perform combo MIT test with LRS. Pressure up A Annulus to 1650 psi for 30 minutes. Released pressure. Equalize and release 2-7/8" CSV. Pull out of the hole and lay down tool string. RDMO Slickline unit. Operation at 07.00 Safety stand down with E-line operations. Prepare to run in the hole with tubing patches. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 06:00 6.00 6.00 PROD- MAN R 1 P No operations at this time. 06:00 09:30 3.50 9.50 PROD- MAN R 15 P PJSM. Make up 2-7/8" Cat Standing Valve BHA. Stab on well. Pressure test lubricator. Test good. Run in the hole as follows: RS, QC, 1-1/16" x 15/16" X-over, 1.5" x 5' RLR Stem with 1.84" wheels, 1.5" x 5' RLR Stem with 1.84" wheels. 1.5" x 5' RLR Stem with 1.84" wheels, QC, 1.5" Oil Jars, QC, KJ, 1.5" Spang Jars, QC, 2-7/8" GR Pulling tool and 2-7/8" Cat Standing Valve. Set CSV at 5480' (2-7/8" x 4-1/2" Nipple Reducer). 09:30 10:30 1.00 10.50 PROD- MAN R 9 P Lined up wellhead valves for production department to load the tubing and annulus with injection water. Used 105 bbls to fill the well. 10:30 11:30 1.00 11.50 PROD- MAN R 12 P Perform combo MIT test with LRS. Pressure up A Annulus to 1650 psi for 30 minutes. Starting pressures as follows: tubing 1519 psi, A Annulus - 1660. After 15 minutes: tubing - 1490 psi, A Annulus - 1629 psi. After 30 minutes: tubing - 1483 psi, A Annulus - 1624 psi. Test good. Released pressure. 11:30 13:30 2.00 13.50 PROD- MAN R 15 P Equalize and release 2-7/8" CSV. Pull out of the hole and lay down tool string. RDMO Slickline unit. 13:30 00:00 10.50 24.00 PROD- MAN R 1 P No operations at this time. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Jody Cornell ASRC Energy Services Co. Man jody.cornell@external.eni.com 907-685-0710 Eni representative Yelyzaveta Saprykina ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Erik Bohlen ASRC Energy Services HSE Eric.Bohlen@external.eni.com 970-685-1434 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.95 L80 -3,848.4 10,594.0 3,687.6 10/12/2010 Well Name: OI11-01 OR Wellbore Name: OI11-01 Well Code: 25056 Job: RIGLESS WCEI Level: N/A Daily Report Date: 7/14/2023 Report #: 10 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code WATER INJECTION WELL Rotary Table Elevation (ft) 53.25 Ground Level (ft) 12.20 First Flange (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) Rig Information Rig Name Contractor Rig Type Rig Num Daily Information Weather Overcast Temperature (°F) 32.3 Wind NE @ 15 MPH Days LTI (days) 2,136.00 Days RI (days) POB 21.0 Daily Summary Operations 24h Forecast Run in the hole and correlate the upper patch setting depth. Set 40' patch and seal off leak at 4564'. Return well to injection for 24 hours to warm up both patches. 24h Summary Added an additional 20' of 5.5" lube to the lubricator assembly. Freeze protect A-annulus with 105 bbls of diesel (55 bbls to fill up the annulus). Make Lower Patch BHA (31.74"). Stab on well. Run in the hole. Correlate depth with the X-Nipple at 2232'. Continue in the hole to 5250'. Pull up hole and make 3 correlation passes from 5250' - 5000'. Position CCL at 5122'. Set patch as follows: leak at 5160', top element at 5140.26', bottom element at 5172'. Explosive charge took 2 minutes and 32 seconds to go off and set patch. All indications showed the patch is set. Pull out of hole. Operation at 07.00 Make up the upper patch BHA. Prepare to run in the hole. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 06:00 6.00 6.00 PROD- MAN R 1 P No operations at this time. 06:00 08:30 2.50 8.50 PROD- MAN R 9 P PJSM followed by a Safety Stand Down covering recent Slick Line and workover lessons learned. Added an additional 20' of 5.5" lube to the lubricator assembly. Worley crane crew extended the job on the crane for the additional lube length being run. Freeze protect A Annulus with 105 bbls of diesel from the production department. NOTE: 55 bbls to fill up the annulus. 08:30 09:30 1.00 9.50 PROD- MAN R 1 P Explosives arrived on location. Made all-call through security for no hot work within 500'. Perform ground integrity checks along with stray voltage checks. 09:30 11:30 2.00 11.50 PROD- MAN R 12 P Make Lower Patch BHA (31.74"). Stab on well. Pressure test lubricator to 2000 psi for 10 minutes. Test good. 11:30 13:30 2.00 13.50 PROD- MAN R 15 P Run in the hole as follows: GPLT, QC, FH, MST & 31.74 Owens Patch. Correlate depth with the X-Nipple at 2232'. Continue in the hole to 5250'. Pull up hole and make 3 correlation passes from 5250' - 5000'. Send data to town for analysis. 13:30 17:00 3.50 17.00 PROD- MAN R 15 P Position CCL at 5122'. Set patch as follows: leak at 5160', top element at 5140.26', bottom element at 5172'. Explosive charge took 2 inutes and 32 seconds to go off and set patch. All indications showed the patch is set. Pull out of hole. Shut well in. Secure wellhead. Explosive are spent and all went well setting the patch. Lay down the lubricator. Prepare equipment to set the upper patch in the morning. 17:00 00:00 7.00 24.00 PROD- MAN R 1 P No operations at this time. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Jody Cornell ASRC Energy Services Co. Man jody.cornell@external.eni.com 907-685-0710 Eni representative Yelyzaveta Saprykina ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Erik Bohlen ASRC Energy Services HSE Eric.Bohlen@external.eni.com 970-685-1434 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.95 L80 -3,848.4 10,594.0 3,687.6 10/12/2010 Well Name: OI11-01 OR Wellbore Name: OI11-01 Well Code: 25056 Job: RIGLESS WCEI Level: N/A Daily Report Date: 7/15/2023 Report #: 11 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code WATER INJECTION WELL Rotary Table Elevation (ft) 53.25 Ground Level (ft) 12.20 First Flange (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) Rig Information Rig Name Contractor Rig Type Rig Num Daily Information Weather Overcast Temperature (°F) 35.8 Wind WN @ 9 MPH Days LTI (days) 2,137.00 Days RI (days) POB 21.0 Daily Summary Operations 24h Forecast Perform MIT Test for leak detection following the 24 hour warm up period. MIT Test scheduled for 14:00 hrs. 24h Summary Make up upper BHA patch and load into the lubricator. Stab on well. Pressure test lubricator. Run in the hole. Correlate depth with the X-Nipple at 2232'. Continue in the hole to 5080' (Top of lower patch). Pull up hole and make 3 correlation passes from 4500' - 5080'. Position CCL at 4525.01'. Set patch. All indications showed the patch is set. Pull out of hole. Shut well in. Secure wellhead. Production department returned well to injection at 14:00 for 24 hour warm up prior to MIT test. Operation at 07.00 No operations at this time. Prepare for MIT test at 14:00 hrs. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 06:00 6.00 6.00 PROD- MAN R 1 P No operations at this time. 06:00 08:00 2.00 8.00 PROD- MAN R 5 P PJSM. Make up upper BHA patch and load into the lubricator. 08:00 09:00 1.00 9.00 PROD- MAN R 25 TW02 Pick up lubricator and tension was not reading correctly. Trouble shoot and make repairs. 09:00 12:00 3.00 12.00 PROD- MAN R 15 P Stab on well. Pressure test lubricator. Test good. Run in the hole as follows: GPLT, QC, FH, MST & 41.74' Owens Patch. Correlate depth with the X-Nipple at 2232'. Continue in the hole to 5080' (Top of lower patch). Pull up hole and make 3 correlation passes from 4500' - 5080'. Send data to town for analysis. 12:00 15:00 3.00 15.00 PROD- MAN R 15 P Position CCL at 4525.01'. Set patch as follows: leak at 4562.5', top element at 4543.26', bottom element at 4585'. Explosive charge took 2.28 minutes to go off and set patch. All indications showed the patch is set. Pull out of hole. Shut well in. Secure wellhead. Explosive are spent and all went well setting the patch. Lay down the lubricator. Production department returned well to production at 14:00 for 24 hour warm up prior to MIT test. 15:00 00:00 9.00 24.00 PROD- MAN R 1 P No operations at this time. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Jody Cornell ASRC Energy Services Co. Man jody.cornell@external.eni.com 907-685-0710 Eni representative Yelyzaveta Saprykina ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Erik Bohlen ASRC Energy Services HSE Eric.Bohlen@external.eni.com 970-685-1434 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.95 L80 -3,848.4 10,594.0 3,687.6 10/12/2010 Well Name: OI11-01 OR Wellbore Name: OI11-01 Well Code: 25056 Job: RIGLESS WCEI Level: N/A Daily Report Date: 7/16/2023 Report #: 12 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code WATER INJECTION WELL Rotary Table Elevation (ft) 53.25 Ground Level (ft) 12.20 First Flange (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) Rig Information Rig Name Contractor Rig Type Rig Num Daily Information Weather Clear Temperature (°F) 40.1 Wind ES @ 7 MPH Days LTI (days) 2,138.00 Days RI (days) POB 13.0 Daily Summary Operations 24h Forecast Waiting until a plan forward has been approved. 24h Summary Current well conditions as follows: tubing injection pressure - 6 psi, A Annulus 151 psi, injection rate at 2300 bbls per day. Shut down injection. Annulus pressure bleed down from 151 psi to 0 psi in 3 minutes. Lined valves for production to fill annulus. Pumped 17 bbls down the A-Annulus and pressured up to 1000 psi. Pressure decreased over 100 psi per minute and quickly went on a vacuum. Shut well in. Secure wellhead. Shut down for the night. Operation at 07.00 Waiting until a plan forward has been approved by the Production and Drilling department. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 14:00 14.00 14.00 PROD- MAN R 1 P No operations at this time. Waiting for the 24 hour patch warm up period. 14:00 16:00 2.00 16.00 PROD- MAN R 9 P PJSM. Current well conditions as follows: tubing injection pressure - 6 psi, A Annulus 151 psi, injection rate at 2300 bbls per day. Shut down injection. Annulus pressure quickly bleed down from 151 psi to 0 psi in 3 minutes. Lined valves for production to fill annulus. Pumped 17 bbls down the A Annulus and pressured up to 1000 psi. Pressure decreased over 100 psi per minute and quickly went on a vacuum. Had discussion with town. Shut well in . Secure wellhead. Shut down for the night. 16:00 00:00 8.00 24.00 PROD- MAN R 1 P No operations at this time. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Jody Cornell ASRC Energy Services Co. Man jody.cornell@external.eni.com 907-685-0710 Eni representative Yelyzaveta Saprykina ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Erik Bohlen ASRC Energy Services HSE Eric.Bohlen@external.eni.com 970-685-1434 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.95 L80 -3,848.4 10,594.0 3,687.6 10/12/2010 Well Name: OI11-01 OR Wellbore Name: OI11-01 Well Code: 25056 Job: RIGLESS WCEI Level: N/A Daily Report Date: 7/17/2023 Report #: 13 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code WATER INJECTION WELL Rotary Table Elevation (ft) 53.25 Ground Level (ft) 12.20 First Flange (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) Rig Information Rig Name Contractor Rig Type Rig Num Daily Information Weather Overcast Temperature (°F) 37.4 Wind N @ 15 MPH Days LTI (days) 2,139.00 Days RI (days) POB 11.0 Daily Summary Operations 24h Forecast Continue leak detection. 24h Summary MIRU Halliburton Slickline unit. Make up BHA with D&D Hole finder. Stab on well. Run in the hole to 4525' (SL Depth). Pull up to 4520' and shear D&D Hole Finder. Set plug. Fill up and pressure up tubing to 500 psi (3x's). Rapid pressure loss immediately after shutting down pump. Release plug and pull up hole to 4020'. Set plug and attempt to pressure test tubing. Unable to fill tubing. Moved up hole to 3800' and attempt to set plug with same results. Pull out of hole. Run in hole to 3300'. Shear pin and set plug at 3300'. Fill tubing and attempt to pressure up tubing. Pumped tubing volume (51 bbls) plus 30 bbls and plug would not seal. Pull up hole to 2798'. Fill tubing and pressure up to 500 psi (3x's) with 75 psi per minute pressure loss. Pull up hole to 2482'. Pressure up tubing to 500 psi (3x's) with 55 psi per minute pressure loss. Pull up hole to 2380' with same results. Pull out of hole. Operation at 07.00 Clean up and redress tool string. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 06:00 6.00 6.00 PROD- MAN R 1 P No operations at this time. 06:00 09:00 3.00 9.00 PROD- MAN R 1 P PJSM with all crews. Waiting until a plan forward has been approved. 09:00 12:00 3.00 12.00 PROD- MAN R 5 P MIRU Halliburton Slickline unit. Make up BHA with D&D Hole finder. 12:00 16:00 4.00 16.00 PROD- MAN R 15 P Stab on well. Pressure test lubricator to 2000 psi for 10 minutes. Test good. Run in the hole to 4525' (SL Depth) as follows: 1.750" RS, 1.750 QC, 2-1/8" x 5' RS, 1.750" QC, 2-1/8" x 10' RS, 1.750" QC, 1.750" x 3' Oil Jars, 1.750" QC, 1.875" x 8' Spangs, 1.750" QC, 2.650" RB & 4.5" D&D Hole Finder. Pull up to 4520' and shear D&D Hole Finder. Set plug. Fill up and pressure up tubing to 500 psi (3x's). Rapid pressure loss immidiatly after shutting down pump. Release plug and pull up hole to 4020'. Set plug and attempt to pressure test tubing. Unable to fill tubing. Moved up hole to 3800' and attempt to set plug with same results. Pull out of hole. 16:00 17:45 1.75 17.75 PROD- MAN R 20 P Lay down tool string and lubricator. Tools hung up in lubricator, cut wire and strip tools from lubricator. Found slips packed off with what appears to be scale. Took samples and sent to Versalis for analysis. Re-dress D&D Hole Finder. Re-head slickline. 17:45 22:00 4.25 22.00 PROD- MAN R 15 P Pick up and stab on well. Pressure test lubricator. Test good. Run in hole to 3300' as follows: 1.750" RS, 1.750 QC, 2-1/8" x 5' RS, 1.750" QC, 2-1/8" x 10' RS, 1.750" QC, 1.750" x 3' Oil Jars, 1.750" QC, 1.875" x 8' Spangs, 1.750" QC, 2.650" RB & 4.5" D&D Hole Finder. Shear pin and set plug at 3300'. Fill tubing and attempt to pressure up tubing. Pumped tubing volume (51 bbls) plus 30 bbls and plug would not seal. Pull up hole to 2798'. Fill tubing and pressure up to 500 psi (3x's). 75 psi per minute pressure loss. Pull up hole to 2482'. Pressure up tubing to 500 psi (3x's) with 55 psi per minute pressure loss. Pull up hole to 2380' with same results. Pull out of hole. Lay down tool string and lubricator. Shut well in. Secure wellhead. Shut down for the night. 22:00 00:00 2.00 24.00 PROD- MAN R 1 P No operations at this time. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Jody Cornell ASRC Energy Services Co. Man jody.cornell@external.eni.com 907-685-0710 Eni representative Yelyzaveta Saprykina ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Erik Bohlen ASRC Energy Services HSE Eric.Bohlen@external.eni.com 970-685-1434 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.95 L80 -3,848.4 10,594.0 3,687.6 10/12/2010 Well Name: OI11-01 OR Wellbore Name: OI11-01 Well Code: 25056 Job: RIGLESS WCEI Level: N/A Daily Report Date: 7/18/2023 Report #: 14 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code WATER INJECTION WELL Rotary Table Elevation (ft) 53.25 Ground Level (ft) 12.20 First Flange (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) Rig Information Rig Name Contractor Rig Type Rig Num Daily Information Weather Clear Temperature (°F) 40.0 Wind NE @ 7 MPH Days LTI (days) 2,140.00 Days RI (days) POB 11.0 Daily Summary Operations 24h Forecast Perform ACX leak detection log from 4543' to surface. Download data from tool string and send into Halliburton for analysis. 24h Summary Make up BHA with 4.5" D&D Hole Finder. Run in the hole and set D&D plug at 2480'. Fill tubing and pressure test to 500 psi for 5 minutes. Lost 5 psi. Bleed off pressure and test again with same results. Release plug and pull up hole to 2380'. Set plug. Load tubing and pressure test to 500 psi for 5 minutes. Lost 50 psi. Re-test with same results. Release plug and pull up hole to 1880'. Set plug. Load tubing and pressure test to 500 psi for 5 minutes losing 50 psi. Release plug and pull up hole to 1380'. Set plug. Load tubing and pressure test to 500 psi for 5 minutes losing 30 psi. Release plug and pull out of hole. Lay down tool string and lubricator. Shut well in. Secure wellhead. Rig down Slickline. Rig up Halliburton E-line. Make up ACX BHA. Perform all electrical checks and prepare tool to run first thing in the morning. Operation at 07.00 Perform ACX leak detection log from 4543' to surface. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 06:00 6.00 6.00 PROD- MAN R 1 P No operations at this time. 06:00 10:00 4.00 10.00 PROD- MAN R 5 P PJSM. Remove tool string from lubricator. Clean and redress tool string. Redress brush and flush tools. 10:00 17:00 7.00 17.00 PROD- MAN R 15 P Make up BHA with 4.5" D&D Hole Finder. Stab on well. Pressure test lubricator. Test good. Run in the hole and set D&D plug at 2480'. Fill tubing and pressure test to 500 psi for 5 minutes. Lost 5 psi. Bleed off pressure and test again with same results. Release plug and pull up hole to 2380'. Set plug. Load tubing and pressure test to 500 psi for 5 minutes. Lost 50 psi. Re-test with same results. Release plug and pull up hole to 1880'. Set plug. Load tubing and pressure test to 500 psi for 5 minutes losing 50 psi. Release plug and pull up hole to 1380'. Set plug. Load tubing and pressure test to 500 psi for 5 minutes losing 30 psi. Release plug and pull out of hole. Lay down tool string and lubricator. Shut well in. Secure wellhead. Rig down Slickline. 17:00 18:00 1.00 18.00 PROD- MAN R 5 P Rig up Halliburton E-line. Make up ACX BHA. Perform all electrical checks and prepare tool to run first thing in the morning. Shut down for the night. 18:00 00:00 6.00 24.00 PROD- MAN R 1 P No operations at this time. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Jody Cornell ASRC Energy Services Co. Man jody.cornell@external.eni.com 907-685-0710 Eni representative Yelyzaveta Saprykina ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Erik Bohlen ASRC Energy Services HSE Eric.Bohlen@external.eni.com 970-685-1434 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.95 L80 -3,848.4 10,594.0 3,687.6 10/12/2010 Well Name: OI11-01 OR Wellbore Name: OI11-01 Well Code: 25056 Job: RIGLESS WCEI Level: N/A Daily Report Date: 7/19/2023 Report #: 15 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code WATER INJECTION WELL Rotary Table Elevation (ft) 53.25 Ground Level (ft) 12.20 First Flange (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) Rig Information Rig Name Contractor Rig Type Rig Num Daily Information Weather Overcast Temperature (°F) 46.0 Wind E @ 15 MPH Days LTI (days) 2,141.00 Days RI (days) POB 11.0 Daily Summary Operations 24h Forecast Prepare to run patch over expected hole at 3300' pending analysis report from Halliburton. 24h Summary Load tool string in lubricator. Execute final electrical checks. Pick up and stab on well. Run in the hole with ACX tool string to 5480' (Nipple Reducer). Lined up valves for production to pump diesel down Annulus. Fill up annulus with 54 bbls of diesel. Establish 500 psi differential between tubing and annulus. Start ACX log from 5480' - surface while maintain 500 psi differential. Lay down tool string and lubricator. Shut well in. Secure wellhead. Download data from logging tools. Log shows anomaly section at 3,300'. Operation at 07.00 Preparing to run patch following analysis report from Halliburton. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 06:00 6.00 6.00 PROD- MAN R 1 P No operations at this time. 06:00 07:45 1.75 7.75 PROD- MAN R 12 P PJSM. Load tool string in lubricator. Execute final electrical checks. Pick up and stab on well. Pressure test lubricator to 2000 psi for 10 minutes. Test good. 07:45 11:30 3.75 11.50 PROD- MAN R 15 P Run in the hole with ACX tool string to 5480' (Nipple Reducer). Lined up valves for production to pump diesel down Annulus. Fill up annulus with 54 bbls of diesel. Establish 500 psi differential between tubing and annulus. 11:30 12:00 0.50 12.00 MOB R 20 P PJSM- Safety Stand Up/ Kick Off meeting with all crews. Discussed safety topics related to upcoming rig work, not taking short cuts, Stop and reassess if operations change, and reinforced SWA. 12:00 17:00 5.00 17.00 PROD- MAN R 15 P Start ACX log from 5480' - surface while maintain 500 psi differential. 157 bbls of diesel used to fill and maintain 500 psi differential. Lay down tool string and lubricator. Shut well in. Secure wellhead. Download data from logging tools. Log shows anomaly section at 3,300'. Shut down for the night. 17:00 00:00 7.00 24.00 PROD- MAN R 1 P No operations at this time. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Jody Cornell ASRC Energy Services Co. Man jody.cornell@external.eni.com 907-685-0710 Eni representative Yelyzaveta Saprykina ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Erik Bohlen ASRC Energy Services HSE Eric.Bohlen@external.eni.com 970-685-1434 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.95 L80 -3,848.4 10,594.0 3,687.6 10/12/2010 Well Name: OI11-01 OR Wellbore Name: OI11-01 Well Code: 25056 Job: RIGLESS WCEI Level: N/A Daily Report Date: 7/20/2023 Report #: 16 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code WATER INJECTION WELL Rotary Table Elevation (ft) 53.25 Ground Level (ft) 12.20 First Flange (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) Rig Information Rig Name Contractor Rig Type Rig Num Daily Information Weather Clear Temperature (°F) 48.0 Wind E @ 10 MPH Days LTI (days) 2,142.00 Days RI (days) POB 11.0 Daily Summary Operations 24h Forecast Clean up equipment, redress tools and prepare to set patches for tubing repair. 24h Summary Standby following analysis results from leak detection log. Operation at 07.00 Clean up equipment, redress tools. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 06:00 6.00 6.00 PROD- MAN R 1 P No operations at this time. 06:00 06:30 0.50 6.50 PROD- MAN R 1 P PJSM with all crews. 06:30 00:00 17.50 24.00 PROD- MAN R 1 P Standby following analysis results from leak detection log. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Jody Cornell ASRC Energy Services Co. Man jody.cornell@external.eni.com 907-685-0710 Eni representative Yelyzaveta Saprykina ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Erik Bohlen ASRC Energy Services HSE Eric.Bohlen@external.eni.com 970-685-1434 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.95 L80 -3,848.4 10,594.0 3,687.6 10/12/2010 Well Name: OI11-01 OR Wellbore Name: OI11-01 Well Code: 25056 Job: RIGLESS WCEI Level: N/A Daily Report Date: 7/21/2023 Report #: 17 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code WATER INJECTION WELL Rotary Table Elevation (ft) 53.25 Ground Level (ft) 12.20 First Flange (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) Rig Information Rig Name Contractor Rig Type Rig Num Daily Information Weather Overcast Temperature (°F) 41.5 Wind ES @ 9 MPH Days LTI (days) 2,143.00 Days RI (days) POB 11.0 Daily Summary Operations 24h Forecast No operations at this time. 24h Summary Suspend operations until all materials have arrived for the tubing leak repair. RDMO Halliburton Slickline and E-line equipment. RDMO Worley crane and Little Red Services. Release Halliburton and Worley Crane equipment. Freeze protect tubing with 30 bbls of diesel. Shut well in and secure wellhead. Operation at 07.00 No operations at this time. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 06:00 6.00 6.00 PROD- MAN R 1 P No operations at this time. 06:00 06:30 0.50 6.50 PROD- MAN R 1 P PJSM with all crews. 06:30 09:30 3.00 9.50 PROD- MAN R 1 P Redress tools and clean up work area. 09:30 15:00 5.50 15.00 PROD- MAN R 1 P Suspend operations until all materials have arrived for the tubing leak repair. RDMO Halliburton Slickline and E-line equipment. RDMO Worley crane and Little Red Services. Release Halliburton and Worley Crane equipment. Freeze protect tubing with 30 bbls of diesel. Shut well in and secure wellhead. 15:00 23:00 8.00 23.00 PROD- MAN R 1 P No operations at this time. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Jody Cornell ASRC Energy Services Co. Man jody.cornell@external.eni.com 907-685-0710 Eni representative Yelyzaveta Saprykina ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Erik Bohlen ASRC Energy Services HSE Eric.Bohlen@external.eni.com 970-685-1434 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.95 L80 -3,848.4 10,594.0 3,687.6 10/12/2010 Well Name: OI11-01 OR Wellbore Name: OI11-01 Well Code: 25056 Job: RIGLESS WCEI Level: N/A Daily Report Date: 8/7/2023 Report #: 18 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code WATER INJECTION WELL Rotary Table Elevation (ft) 53.25 Ground Level (ft) 12.20 First Flange (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) Rig Information Rig Name Contractor Rig Type Rig Num Daily Information Weather Partly Cloudy Temperature (°F) 41.7 Wind NE @ 7MPH Days LTI (days) 2,144.00 Days RI (days) POB 11.0 Daily Summary Operations 24h Forecast Perform brush and flush run with 3.79" gauge ring and 4-1/2" tubing brush on E-line. Run in hole and set tubing patch on E-line from 3,552.37' to 3,530.63'. 24h Summary Mobilize Equipment to location, Received well from Production group. Held lift meeting and pre job safety meeting. Spot in Halliburton equipment and Worley crane. Install secondary swab valve, BOPS and valves with night cap. Lay out lubricator and rig up pressure control equipment. Operation at 07.00 Perform brush and flush run with 3.79" gauge ring and 4-1/2" tubing brush on E-line. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 06:00 09:00 3.00 3.00 PROD- MAN R 2 P Mobilize Halliburton, Worley crane, and LRS to location. 09:00 10:30 1.50 4.50 PROD- MAN R 1 P Received well from Production group. Held lift meeting with Worley, Production Operator, Halliburton and LRS. Pre job safety meeting with all personnel. Review ENI Safety Alert 26/06/2023 (Contractor hit by slick line sheave Rig Less Operations). Perform EIP walk down with Production Operator and Halliburton. 10:30 18:00 7.50 12.00 PROD- MAN R 1 P Lay out containment and spot in equipment. Remove tree cap, install secondary swab valve, and wire line BOP with night cap. Laid out lubricator. Rig up pressure control equipment. ENI Company rep witnessed function test wire line valves and check hose alignment to pressure control equipment, good function test. 18:00 00:00 6.00 18.00 PROD- MAN R 1 P No operations at this time Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Paul Dillon ASRC Energy Services Co. Man Paul.Dillon@external.eni.com 907-685-0710 Eni representative Craig Smith ASRC Energy Services Co. Man Craig.Smith@external.eni.com 907-685-0710 Safety Representative Tyler Rush ASRC Energy Services HSE Tyler.Rush@external.eni.com 970-685-6622 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.95 L80 -3,848.4 10,594.0 3,687.6 10/12/2010 Well Name: OI11-01 OR Wellbore Name: OI11-01 Well Code: 25056 Job: RIGLESS WCEI Level: N/A Daily Report Date: 8/8/2023 Report #: 19 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code WATER INJECTION WELL Rotary Table Elevation (ft) 53.25 Ground Level (ft) 12.20 First Flange (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) Rig Information Rig Name Contractor Rig Type Rig Num Daily Information Weather Foggy Temperature (°F) 41.9 Wind NE @ 9MPH Days LTI (days) 2,145.00 Days RI (days) POB 12.0 Daily Summary Operations 24h Forecast Run in the hole and correlate Owens tubing patch #4. Set 20' patch and seal off leak at 3537'. 24h Summary Brush and flush tubing patch setting areas with 4-1/2" tubing brush on E-line. Run in hole with Owens tubing patch #3 on E-line. Set patch from 3737.87' to 3703.13'. Pull out of hole with E-line and lay down lubricator. Secure well with nightcap. Operation at 07.00 Pre job meeting with contractors. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 06:00 6.00 6.00 PROD- MAN R 1 P No operations at this time. 06:00 08:00 2.00 8.00 PROD- MAN R 1 P PJSM, Perform safety checks on Halliburton, Worley, and LRS equipment. Obtain permit to work from Operations. Obtain well pressures; SITP -14 PSI, A-Annulus -14 PSI, B-Annulus 160 PSI. 08:00 09:00 1.00 9.00 PROD- MAN R 12 P Make up 3.79" gauge ring and 4-1/2" tubing brush BHA with 2.6" roller stem, long stroke spang jars, and oil jars, Total Wt. 250 LBS, Overall length 33.83', CCL offset to gauge ring 30.91'. Remove nightcap and stab lubricator onto well. Pressure test lubricator to 250 PSI for 5 minutes and 2000 PSI for 10 minutes, good test. 09:00 13:00 4.00 13.00 PROD- MAN R 15 P Run in hole with 3.79" gauge ring and 4-1/2" tubing brush on E-line to top of tubing patch #2 at 4,543.26' MD. Pull up to GLM at 2,133.19' MD and correlate. Perform brush and flush pumping total of 85 BBLs of diesel while brushing the following areas 6 times each in preparation to set tubing patches; X-nipple at 2239.92', 3,250' to 3,400', 3,500' to 3,600', and 3,650' to 3,775'. Pull out of hole with E-line. 13:00 14:00 1.00 14.00 PROD- MAN R 5 P Lay down lubricator and break down tool string. 14:00 16:00 2.00 16.00 PROD- MAN R 5 P Perform all call with security. Make up owen tubing patch and stab on well. Pressure test lubricator to 250 PSI for 5 minutes and 2000 PSI for 10 minutes, good test. 16:00 20:00 4.00 20.00 PROD- MAN R 15 P Run in the hole as follows: GPLT, QC, FH, MST & 31.74' Owens Patch. Correlate depth with the X-Nipple at 2232'. Continue in the hole to 4543.26' (Top of patch number two). Pull up hole and make 2 correlation passes from 4543.23' - 2050'. Send data to town for analysis. 20:00 23:00 3.00 23.00 PROD- MAN R 15 P Position CCL at 3692.47'. Set patch as follows: top element at 3703.13', bottom element at 3737.87'. Explosive charge took 4.28 minutes to go off and set patch. All indications showed the patch is set. Pull out of hole. Shut well in. Secure wellhead with nightcap. Explosive are spent and all went well setting the patch. Lay down the lubricator. 23:00 00:00 1.00 24.00 PROD- MAN R 1 P No operations at this time. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Paul Dillon ASRC Energy Services Co. Man Paul.Dillon@external.eni.com 907-685-0710 Eni representative Craig Smith ASRC Energy Services Co. Man Craig.Smith@external.eni.com 907-685-0710 Safety Representative Tyler Rush ASRC Energy Services HSE Tyler.Rush@external.eni.com 970-685-6622 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.95 L80 -3,848.4 10,594.0 3,687.6 10/12/2010 Well Name: OI11-01 OR Wellbore Name: OI11-01 Well Code: 25056 Job: RIGLESS WCEI Level: N/A Daily Report Date: 8/9/2023 Report #: 20 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code WATER INJECTION WELL Rotary Table Elevation (ft) 53.25 Ground Level (ft) 12.20 First Flange (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) Rig Information Rig Name Contractor Rig Type Rig Num Daily Information Weather Foggy Temperature (°F) 47.7 Wind E @ 18 MPH Days LTI (days) 2,146.00 Days RI (days) POB 12.0 Daily Summary Operations 24h Forecast Run in the hole and correlate Owens tubing patch #4. Set 20' patch and seal off leak at 3537'. 24h Summary Life critical operations suspended due to Phase 3 conditions of excessive fog. Operation at 07.00 Life critical operations suspended due to Phase 3 conditions of excessive fog. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 07:00 7.00 7.00 PROD- MAN R 1 P No operations at this time. 07:00 18:00 11.00 18.00 PROD- MAN R 1 TW01 Pre job safety meeting with Halliburton, Worley, and LRS. Life critical operations suspended due to Phase 3 conditions of excessive fog. 18:00 00:00 6.00 24.00 PROD- MAN R 1 P No operations at this time. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Paul Dillon ASRC Energy Services Co. Man Paul.Dillon@external.eni.com 907-685-0710 Eni representative Craig Smith ASRC Energy Services Co. Man Craig.Smith@external.eni.com 907-685-0710 Safety Representative Tyler Rush ASRC Energy Services HSE Tyler.Rush@external.eni.com 970-685-6622 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.95 L80 -3,848.4 10,594.0 3,687.6 10/12/2010 Well Name: OI11-01 OR Wellbore Name: OI11-01 Well Code: 25056 Job: RIGLESS WCEI Level: N/A Daily Report Date: 8/10/2023 Report #: 21 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code WATER INJECTION WELL Rotary Table Elevation (ft) 53.25 Ground Level (ft) 12.20 First Flange (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) Rig Information Rig Name Contractor Rig Type Rig Num Daily Information Weather Fog Temperature (°F) 41.0 Wind NE @15-25 MPH Days LTI (days) 2,147.00 Days RI (days) POB 12.0 Daily Summary Operations 24h Forecast Run in the hole and correlate Owens tubing patch #4. Set 20' patch and seal off leak at 3537'. 24h Summary Life critical operations suspended due to Phase 3 conditions of excessive fog. After Phase 3 conditions lifted operations remained suspended due to high winds exceeding max crane working limit. Operation at 07.00 Make up Owens tubing patch and prepare to run in hole on E-line. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 06:00 6.00 6.00 PROD- MAN R 1 P No operations at this time. 06:00 18:00 12.00 18.00 PROD- MAN R 1 TW01 Life critical operations suspended due to Phase 3 conditions of excessive fog until 0800 HRS. After Phase 3 conditions lifted operations remained suspended due to high winds exceeding max crane wotking limit of 25 MPH. Held pre job safety meeting with all personnel. Review ENI Safety Alert 26/06/2023 (Contractor hit by slick line sheave during Rig Less Operations) and lift plan with crew members after crew change was made. 18:00 00:00 6.00 24.00 PROD- MAN R 1 P No operations at this time. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Paul Dillon ASRC Energy Services Co. Man Paul.Dillon@external.eni.com 907-685-0710 Eni representative Craig Smith ASRC Energy Services Co. Man Craig.Smith@external.eni.com 907-685-0710 Safety Representative Tyler Rush ASRC Energy Services HSE Tyler.Rush@external.eni.com 970-685-6622 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.95 L80 -3,848.4 10,594.0 3,687.6 10/12/2010 Well Name: OI11-01 OR Wellbore Name: OI11-01 Well Code: 25056 Job: RIGLESS WCEI Level: N/A Daily Report Date: 8/11/2023 Report #: 22 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code WATER INJECTION WELL Rotary Table Elevation (ft) 53.25 Ground Level (ft) 12.20 First Flange (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) Rig Information Rig Name Contractor Rig Type Rig Num Daily Information Weather Partly Cloudy Temperature (°F) 42.0 Wind NE @ 8 MPH Days LTI (days) 2,148.00 Days RI (days) POB 13.0 Daily Summary Operations 24h Forecast Run in the hole and correlate Owens tubing patch #4. Set 20' patch and seal off leak at 3537'. 24h Summary Run in hole with Owens tubing patch #4 on E-line, set down at 3672.13' MD. Pull out of hole with E-line and lay down Owens tubing patch. Perform brush and flush run on E-line with 3.79" gauge ring and 4-1/2" tubing brush to clear obstruction at 3672.13' MD. Pull out of hole with E-line. Lay down lubricator and secure well with nightcap. Operation at 07.00 Make up Owens tubing patch and prepare to run in hole on E-line. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 06:00 6.00 6.00 PROD- MAN R 1 P No operations at this time. 06:00 07:30 1.50 7.50 PROD- MAN R 1 P PJSM, Perform safety checks on Halliburton, Worley, and LRS equipment. Obtain permit to work from Operations. Obtain well pressures; SITP -14 PSI, A-Annulus -14 PSI, B-Annulus 160 PSI. 07:30 09:00 1.50 9.00 PROD- MAN R 5 P Perform all call with security. Make up owen tubing patch and stab on well. Pressure test lubricator to 250 PSI for 5 minutes and 2000 PSI for 10 minutes, good test. 09:00 13:00 4.00 13.00 PROD- MAN R 15 P Run in the hole as follows: GPLT, QC, FH, MST & 21.74' Owens Patch. Correlate depth with the X-Nipple at 2232'. Continue in the hole and set down at 3672.2' MD, (Top of patch #3 at 3706.13' MD, Setting down 29.93' high). Pull up hole and make 2 correlation passes with same results. Pull out of hole with E-line. 13:00 14:00 1.00 14.00 PROD- MAN R 5 P Perform all call with security. PJSM with Halliburton, Worley, and LRS. discussed laying down lubricator and Owens tubing patch. Lay down lubricator and Owens tubing patch. 14:00 15:00 1.00 15.00 PROD- MAN R 12 P Make up 3.79" gauge ring and 4-1/2" tubing brush BHA with 2.6" roller stem, long stroke spang jars, and oil jars, Total Wt. 250 LBS, Overall length 33.83', CCL offset to gauge ring 30.91'. Pressure test lubricator to 250 PSI for 5 minutes and 2000 PSI for 10 minutes, good test. 15:00 19:30 4.50 19.50 PROD- MAN R 15 P Run in hole with 3.79" gauge ring and 4-1/2" tubing brush on E-line to top of tubing patch #3 at 3706.13' MD. Pull up to GLM at 2,133.19' MD and correlate. Went back down for second pass and hung up picking up at 3672' after tagging top of tubing patch #3 at 3706.13' MD. Perform brush and flush pumping total of 20 BBLs of diesel while working thru obstruction at 3672'. Max 755 lbs over line tension. Worked area until clean pickup with no obstructions. Pull out of hole with E-line. 19:30 20:30 1.00 20.50 PROD- MAN R 15 P Shut well in. Secure wellhead with nightcap. Lay down the lubricator. Inspect 3.79" gauge ring with no visual damage. 20:30 00:00 3.50 24.00 PROD- MAN R 1 P No operations at this time. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Paul Dillon ASRC Energy Services Co. Man Paul.Dillon@external.eni.com 907-685-0710 Eni representative Craig Smith ASRC Energy Services Co. Man Craig.Smith@external.eni.com 907-685-0710 Safety Representative Tyler Rush ASRC Energy Services HSE Tyler.Rush@external.eni.com 970-685-6622 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.95 L80 -3,848.4 10,594.0 3,687.6 10/12/2010 Well Name: OI11-01 OR Wellbore Name: OI11-01 Well Code: 25056 Job: RIGLESS WCEI Level: N/A Daily Report Date: 8/12/2023 Report #: 23 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code WATER INJECTION WELL Rotary Table Elevation (ft) 53.25 Ground Level (ft) 12.20 First Flange (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) Rig Information Rig Name Contractor Rig Type Rig Num Daily Information Weather Drizzle / Mist Temperature (°F) 41.0 Wind E @ 13 MPH Days LTI (days) 2,149.00 Days RI (days) POB 13.0 Daily Summary Operations 24h Forecast Pull out of hole with E-line. Return well to injection for 24 hours to warm up tubing patches prior to MIT testing. 24h Summary Run in the hole and correlate Owens tubing patch #4. Set 20' patch and seal off leak at 3537'. Pull out of the hole and lay down tools. Run in the hole and correlate Owens tubing patch #5. Set 40' patch and seal off leak at 3,318'. Attempt to pull free setting tool without success. Operation at 07.00 No operations at this time. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 06:00 6.00 6.00 PROD- MAN R 1 P No operations at this time. 06:00 07:30 1.50 7.50 PROD- MAN R 1 P PJSM, Perform safety checks on Halliburton, Worley, and LRS equipment. Obtain permit to work from Operations. Obtain well pressures; SITP -14 PSI, A-Annulus -14 PSI, B-Annulus 160 PSI. Re-head rope socket on E-line. 07:30 09:00 1.50 9.00 PROD- MAN R 5 P PJSM, Perform all call with security, check for stray voltage, check fire, begin arming setting tool. Make up Owen tubing patch and stab on well. Pressure test lubricator to 250 PSI for 5 minutes and 2000 PSI for 10 minutes, good test. 09:00 15:00 6.00 15.00 PROD- MAN R 15 P Run in the hole as follows: GPLT, QC, FH, MST & 21.74' Owens Patch. Correlate depth with the X-Nipple at 2232'. Continue in the hole to 3600' MD, Pull up hole and make 2 correlation passes. Send data to town for analysis. Position CCL at 3516.97'. Set patch as follows: top element at 3530.63', bottom element at 3552.37'. Explosive charge took 4.24 minutes to go off and set patch. All indications showed the patch is set. Pull out of hole with E-line. 15:00 16:00 1.00 16.00 PROD- MAN R 5 P PJSM with Halliburton, Worley, and LRS. Lay down lubricator and break down tool string. 16:00 17:00 1.00 17.00 PROD- MAN R 5 P PJSM, Perform all call with security, check for stray voltage, check fire, begin arming setting tool. Make up Owen tubing patch and stab on well. Pressure test lubricator to 250 PSI for 5 minutes and 2000 PSI for 10 minutes, good test. 17:00 23:00 6.00 23.00 PROD- MAN R 15 P Run in the hole as follows: GPLT, QC, FH, MST & 41.74' Owens Patch. Correlate depth with the X-Nipple at 2232'. Continue in the hole to 3530.63' MD, top of tubing patch #4, Pull up hole and make 2 correlation passes. Send data to town for analysis. Position CCL at 3290.47'. Set patch as follows: top element at 3304.13', bottom element at 3345.87'. Explosive charge after 4 minutes from firing, line tension dropped from 1220 LBS to 1026 LBS. Wait until 10 minutes had expired before attempting to pickup. Pick up and had over pull of line tension, setting tool is stuck in patch. Attempting to free setting tool pulling over tension at 70% to 3500 lbs. Pump 10 bbl of LVT with LRS and continue to work setting tool free without success. 23:00 00:00 1.00 24.00 PROD- MAN R 1 P No operations at this time. Monitor well with 3500 lbs line tension on E-line. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Paul Dillon ASRC Energy Services Co. Man Paul.Dillon@external.eni.com 907-685-0710 Eni representative Craig Smith ASRC Energy Services Co. Man Craig.Smith@external.eni.com 907-685-0710 Safety Representative Tyler Rush ASRC Energy Services HSE Tyler.Rush@external.eni.com 970-685-6622 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.95 L80 -3,848.4 10,594.0 3,687.6 10/12/2010 Well Name: OI11-01 OR Wellbore Name: OI11-01 Well Code: 25056 Job: RIGLESS WCEI Level: N/A Daily Report Date: 8/13/2023 Report #: 24 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code WATER INJECTION WELL Rotary Table Elevation (ft) 53.25 Ground Level (ft) 12.20 First Flange (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) Rig Information Rig Name Contractor Rig Type Rig Num Daily Information Weather Drizzle / Mist Temperature (°F) 39.0 Wind NE @ 7 MPH Days LTI (days) 2,150.00 Days RI (days) POB 13.0 Daily Summary Operations 24h Forecast Pull out of hole with E-line. Swap over to Slickline and fish Owens tubing patch setting tool. 24h Summary Working E-Line attempt to pull free patch setting tool. Pulling over tension F/ 3500 LBS to 5,200 LBS in 100 LBS increments continue to work setting tool free with out success. Operation at 07.00 No operations at this time. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 06:00 6.00 6.00 PROD- MAN R 1 P No operations at this time. Monitor well with 3500 lbs line tension on E-line. 06:00 18:00 12.00 18.00 PROD- MAN R 15 U Working E-Line attempt to pull free patch setting tool. Pulling over tension at 70% to 3500, continue to work setting tool free without success. Teams meeting with town discuss plan forward 18:00 19:00 1.00 19.00 PROD- MAN R 1 U PJSM, ENI company reps, SIMOPS authority, Halliburton, Worley crane crew, LRS, Owens, and Production operators. Discuss plan forward pulling E-line tools free. Obtain permit to work from Operations. 19:00 22:00 3.00 22.00 PROD- MAN R 9 U Pull tension on E-Line at 3,450 LBS, Pumped 100 bbl's of fresh water with 2.5% Enviro-Torq and 2.2 lbs/bbl Xanthan gum at 2 bpm tubing pressure 40 psi, Then Reduced pump rate to1/2 bbl with tubing on vacuum. Started pulling working E-Line at 3,400 LBS over pull wait 5 min each time working line tension up to 5,100 LBS in 100 LBS increment.Continue to work setting tool free without success. Pumped total 125 bbls of fluid attempting to work free E-line. 22:00 00:00 2.00 24.00 PROD- MAN R 1 P No operations at this time. Monitor well. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Paul Dillon ASRC Energy Services Co. Man Paul.Dillon@external.eni.com 907-685-0710 Eni representative Craig Smith ASRC Energy Services Co. Man Craig.Smith@external.eni.com 907-685-0710 Safety Representative Tyler Rush ASRC Energy Services HSE Tyler.Rush@external.eni.com 970-685-6622 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.95 L80 -3,848.4 10,594.0 3,687.6 10/12/2010 Well Name: OI11-01 OR Wellbore Name: OI11-01 Well Code: 25056 Job: RIGLESS WCEI Level: N/A Daily Report Date: 8/14/2023 Report #: 25 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code WATER INJECTION WELL Rotary Table Elevation (ft) 53.25 Ground Level (ft) 12.20 First Flange (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) Rig Information Rig Name Contractor Rig Type Rig Num Daily Information Weather Drizzle / Mist Temperature (°F) 42.0 Wind NE @ 12 MPH Days LTI (days) 2,151.00 Days RI (days) POB 13.0 Daily Summary Operations 24h Forecast Swap E-line to Slick line and crane equipment. Fishing operations for tubing patch setting tool with Slick line. 24h Summary Pulled E-line loose from rope socket. Pull out of hole with E-line. Lay down lubricator and secure well with nightcap. Preparing to swap from E-line to Slick line and crane equipment. Operation at 07.00 Swap E-line to Slick line and crane equipment. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 08:30 8.50 8.50 PROD- MAN R 1 P No operations at this time. 08:30 09:30 1.00 9.50 PROD- MAN R 1 U PJSM, ENI company reps, SIMOPS authority, Halliburton, Worley crane crew, LRS, Owens, and Production operators. Discuss plan forward pulling E-line tools free. Obtain permit to work from Operations. 09:30 14:00 4.50 14.00 PROD- MAN R 15 U Added additional weight to lower sheave block anchor point for E-line. Freeze protected tubing with 35 BBLs of diesel. Pulled line tension from 3500 LBS to 5300 LBS in 100 LB increments before movement of wire. Pulled out of hole with E-line slow and observed a 146 LB reduction in line tension at 2835' WLM. Continure pull out of hole with no recovery at surface. PJSM and pulled E-line thru grease head and secured well. Top of fish at 3288.11' MD. Length of fish left in tubing 57.73'. 14:00 18:00 4.00 18.00 PROD- MAN R 5 U Lay down lubricator and remove pressure control lines from grease head. Preparing to swap from E-line to Slick line and crane equipment. 18:00 00:00 6.00 24.00 PROD- MAN R 1 P No operations at this time. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Paul Dillon ASRC Energy Services Co. Man Paul.Dillon@external.eni.com 907-685-0710 Eni representative Craig Smith ASRC Energy Services Co. Man Craig.Smith@external.eni.com 907-685-0710 Safety Representative Tyler Rush ASRC Energy Services HSE Tyler.Rush@external.eni.com 970-685-6622 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.95 L80 -3,848.4 10,594.0 3,687.6 10/12/2010 Well Name: OI11-01 OR Wellbore Name: OI11-01 Well Code: 25056 Job: RIGLESS WCEI Level: N/A Daily Report Date: 8/15/2023 Report #: 26 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code WATER INJECTION WELL Rotary Table Elevation (ft) 53.25 Ground Level (ft) 12.20 First Flange (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) Rig Information Rig Name Contractor Rig Type Rig Num Daily Information Weather Drizzle / Mist Temperature (°F) 44.0 Wind NE @ 3 MPH Days LTI (days) 2,152.00 Days RI (days) POB 13.0 Daily Summary Operations 24h Forecast Run in hole with 3.5" impression block. Fishing operations for tubing patch setting tool with Slick line. 24h Summary Swap from E-line to Slick line and crane equipment. Make up 3.8" lead impression block BHA and run in hole 2112', unable to work through. Pull out of hole with slick line and lay down tools and lubricator and secure well. Operation at 07.00 Make up and run in hole with 3.5" lead impression block. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 06:00 6.00 6.00 PROD- MAN R 1 P No operations at this time. 06:00 10:30 4.50 10.50 PROD- MAN R 1 U Continue swapping over from E-line to Slick line and crane equipment. 10:30 11:30 1.00 11.50 PROD- MAN R 1 U Held lift meeting with ENI safety, SIMOPS authority, Halliburton, Worley crane crew, LRS, Owens, and Production operators. Held pre job safety meeting. Discuss rig up operations with lubricator and pressure control equipment.. Obtain permit to work from Operations. 11:30 17:30 6.00 17.50 PROD- MAN R 5 U Make up 3.8" lead impression block BHA with 2.62" roller stem, short spang jars, and oil jars, Total Wt. 225 LBS, Overall length 27.66'. Add additional lubricator for total length of 97'. Remove nightcap and stab lubricator onto well. Pressure test lubricator to 250 PSI for 5 minutes and 2000 PSI for 10 minutes, good test. 17:30 21:30 4.00 21.50 PROD- MAN R 15 U Run in hole with 3.8" lead impression block. Work through well head at surface several spots.Estimated fluid level at 1256'. Continue to run in hole to 2112' SLM, GLM at 2133' MD, attempt to work through with no success. Slight over pull when initially coming up of 400 pounds over pull then dropped off. Pull slick line out of hole, lay down impression block and BHA. Lay down lubricator and secure well with nightcap. 21:30 00:00 2.50 24.00 PROD- MAN R 1 P No operations at this time. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Paul Dillon ASRC Energy Services Co. Man Paul.Dillon@external.eni.com 907-685-0710 Eni representative Justin Hayes ASRC Energy Sevices Co Man justin.hayes@external.eni.com 907-685-0710 Eni representative Mike Grubb ASRC Energy Sevices Co Man michael.grubb@external.eni.com 907-685-0710 Eni representative Lorin Reed ASRC Energy Services SOA lorin.reed@external.eni.com 907-685-0718 Safety Representative Jack Potter ASRC Energy Services HSE Jack.Potter@External.eni.com 970-685-1434 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.95 L80 -3,848.4 10,594.0 3,687.6 10/12/2010 Well Name: OI11-01 OR Wellbore Name: OI11-01 Well Code: 25056 Job: RIGLESS WCEI Level: N/A Daily Report Date: 8/16/2023 Report #: 27 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code WATER INJECTION WELL Rotary Table Elevation (ft) 53.25 Ground Level (ft) 12.20 First Flange (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) Rig Information Rig Name Contractor Rig Type Rig Num Daily Information Weather Partly Cloudy Temperature (°F) 47.0 Wind NE @ 8 MPH Days LTI (days) 2,153.00 Days RI (days) POB 13.0 Daily Summary Operations 24h Forecast Perform fishing operations for tubing patch setting tool with Slick line.Rehead slick line and cut wire. Make up 2" JD pulling tool, with 3.6" bell guides,2.62" roller stem, long stroke spang jars, and oil jars. RIH and engage top of fish. work wire and jars staging up in 500 lbs increments to a maximum of 3,000 lbs. 24h Summary Perform fishing operations for tubing patch setting tool with Slick line. Make up 3.5" lead impression block BHA and run in hole to top of fish at 3260' SLM. Lay down impression block and inspect. Make up 2" RS pulling tool, RIH and engage top of fish. Pick up on wire to 800 lbs, fire jars. slack off and repeat picking up to 900 lbs. Repeat picking up to 1,000 lbs and sheared out. POOH to surface. Make up 2" JD pulling tool, RIH and engage top of fish. work wire and jars staging up in 500 lbs increments to a maximum of 3,000 lbs. Jar for one hour and intentionally release pulling tool. POOH to surface. Operation at 07.00 Perform fishing operations for tubing patch setting tool with Slick line. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 06:00 6.00 6.00 PROD- MAN R 1 P No operations at this time. 06:00 08:00 2.00 8.00 PROD- MAN R 1 U Hold pre-job safety meeting with LRS, Halliburton, Worley crane crew, Owens, and production operators. Obtain permit to work from operations. 08:00 10:00 2.00 10.00 PROD- MAN R 5 U Make up 3.5" lead impression block BHA with 2.62" roller stem, short spang jars, and oil jars, Total Wt. 225 LBS, Overall length 32.08'. Total lubricator length of 97'. Remove nightcap and stab lubricator onto well. Pressure test lubricator to 250 PSI for 5 minutes and 2000 PSI for 10 minutes, good test. 10:00 11:00 1.00 11.00 PROD- MAN R 15 U Run in hole with 3.5" lead impression block. No issue passing through well head at surface. Estimated fluid level at 1256'. Continue to run in hole to top of fish at 3260' SLM, Exercise spang jars one time. Pull slick line out of hole, 11:00 12:00 1.00 12.00 PROD- MAN R 5 U Lay down impression block and inspect. Clear indication of no obstruction above fishing neck on fish. 12:00 14:00 2.00 14.00 PROD- MAN R 15 U Make up 2" RS pulling tool, with 3.6" and 2.6" bell guides,2.62" roller stem, long stoker spang jars, and oil jars, Total Wt. 240 LBS, Overall length 32.17'. Total lubricator length of 97'.and stab lubricator onto well. Pressure test lubricator to 250 PSI for 5 minutes and 2000 PSI for 10 minutes, good test. RIH and engage top of fish. Pick up on wire to 800 lbs, fire jars. slack off and repeat picking up to 900 lbs. Repeat picking up to 1,000 lbs and sheared out. POOH to surface. 14:00 18:00 4.00 18.00 PROD- MAN R 15 U Make up 2" JD pulling tool, with 3.6" bell guides,2.62" roller stem, long stroke spang jars, and oil jars, Total Wt. 240 LBS, Overall length 34.75'. Total lubricator length of 97'.and stab lubricator onto well. Pressure test lubricator to 250 PSI for 5 minutes and 2000 PSI for 10 minutes, good test. RIH and engage top of fish. work wire and jars staging up in 500 lbs increments to a maximum of 3,000 lbs. Jar for one hour and intentionally release pulling tool. POOH to surface. 18:00 19:30 1.50 19.50 PROD- MAN R 15 U Pull out of hole, lay down tools and lubricator. Install night cap. 19:30 00:00 4.50 24.00 PROD- MAN R 1 P No operations at this time. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Paul Dillon ASRC Energy Services Co. Man Paul.Dillon@external.eni.com 907-685-0710 Eni representative Justin Hayes ASRC Energy Sevices Co Man justin.hayes@external.eni.com 907-685-0710 Eni representative Mike Grubb ASRC Energy Sevices Co Man michael.grubb@external.eni.com 907-685-0710 Eni representative Lorin Reed ASRC Energy Services SOA lorin.reed@external.eni.com 907-685-0718 Safety Representative Jack Potter ASRC Energy Services HSE Jack.Potter@External.eni.com 970-685-1434 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.95 L80 -3,848.4 10,594.0 3,687.6 10/12/2010 Well Name: OI11-01 OR Wellbore Name: OI11-01 Well Code: 25056 Job: RIGLESS WCEI Level: N/A Daily Report Date: 8/17/2023 Report #: 28 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code WATER INJECTION WELL Rotary Table Elevation (ft) 53.25 Ground Level (ft) 12.20 First Flange (ft) RKB - Base Flange (ft)RKB - Tubing Spool (ft) Rig Information Rig Name Contractor Rig Type Rig Num Daily Information Weather Shower Temperature (°F) 52.0 Wind NE @ 11 MPH Days LTI (days) 2,154.00 Days RI (days) POB 13.0 Daily Summary Operations 24h Forecast Rig down wire line equipment. Hand over well to production. 24h Summary Lifting operations suspended due to high winds. Perform fishing operations for tubing patch setting tool with Slick line.Rehead slick line and cut wire. Make up 2" JD pulling tool, with 3.6" bell guides,2.62" roller stem, long stroke spang jars, and oil jars. RIH and engage top of fish. work wire and jars staging up in 500 lbs increments to a maximum of 3,000 lbs. Operation at 07.00 Finish rigging down wire line equipment. Prepare to hand over well to production. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 06:00 6.00 6.00 PROD- MAN R 1 P No operations at this time. 06:00 07:00 1.00 7.00 PROD- MAN R 1 U Hold pre-job safety meeting with LRS, Halliburton, Worley crane crew, Owens, and production operators. Obtain permit to work from operations. 07:00 09:30 2.50 9.50 PROD- MAN R 1 U Cut wire and tie new rope socket. Make up 2" JD pulling tool, with 3.6" bell guides,2.62" roller stem, long stroke spang jars, and oil jars, Total Wt. 310 LBS, Overall length 34.75'. Total lubricator length of 97'. Lay down tools and lubricator due to increasing winds. 09:30 12:30 3.00 12.50 PROD- MAN R 22 TW01 Suspend lifting operations due to high wind 12:30 13:30 1.00 13.50 PROD- MAN R 1 U Hold pre-job safety meeting. Stab lubricator onto well. Pressure test lubricator to 250 PSI for 5 minutes and 2000 PSI for 10 minutes, good test. 13:30 15:30 2.00 15.50 PROD- MAN R 15 U RIH and engage top of fish on depth of 3,260' SLM, 3,288' MD. work wire and jars staging up in 500 lbs increments to a maximum of 2,700 lbs. Jar for one 30 minutes and pulling tool released. Hit long spangs 20 times and hit with oil jars and spangs 30 times. Max pull while jarring fish was 2,700 LBS. POOH to surface. 15:30 17:00 1.50 17.00 PROD- MAN R 1 U Pop off lubricator from wellhead and inspect JD pulling tool BHA. Skirt around fingers failed and approx. thickness .23 heigh .487 Length 1.10 17:00 18:00 1.00 18.00 PROD- MAN R 1 P Hold teams meeting with anchorge for plan forward. Decision made to suspend fishing operations. 18:00 19:00 1.00 19.00 PROD- MAN R 1 U Lay down lubricator and install night cap. 19:00 00:00 5.00 24.00 PROD- MAN R 1 U No operations at this time. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Paul Dillon ASRC Energy Services Co. Man Paul.Dillon@external.eni.com 907-685-0710 Eni representative Justin Hayes ASRC Energy Sevices Co Man justin.hayes@external.eni.com 907-685-0710 Eni representative Mike Grubb ASRC Energy Sevices Co Man michael.grubb@external.eni.com 907-685-0710 Eni representative Lorin Reed ASRC Energy Services SOA lorin.reed@external.eni.com 907-685-0718 Safety Representative Jack Potter ASRC Energy Services HSE Jack.Potter@External.eni.com 970-685-1434 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.95 L80 -3,848.4 10,594.0 3,687.6 10/12/2010 Well Name: OI11-01 OR Wellbore Name: OI11-01 Well Code: 25056 Job: RIGLESS WCEI Level: N/A Daily Report Date: 8/18/2023 Report #: 29 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code WATER INJECTION WELL Rotary Table Elevation (ft) 53.25 Ground Level (ft) 12.20 First Flange (ft) RKB - Base Flange (ft)RKB - Tubing Spool (ft) Rig Information Rig Name Contractor Rig Type Rig Num Daily Information Weather Partly Cloudy Temperature (°F) 43.0 Wind NW @ 8 MPH Days LTI (days) 2,155.00 Days RI (days) POB 12.0 Daily Summary Operations 24h Forecast Final report. Well handed over to production. 24h Summary Rig down Little Red Services and de-mobilize Halliburton slickline, Worley crane and crew, Owens. Test tree cap to 300 PSI. Hand well over to production Operation at 07.00 Final report. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 06:00 6.00 6.00 PROD- MAN R 1 P No operations at this time. 06:00 00:00 18.00 24.00 PROD- MAN R5UTest tree cap to 300 PSI. Rig down Little Red Services and demobolize Halliburton slickline, Worley crane, Owen. /DVW 5HSRUWIRU2,2SHUDWLRQV Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Justin Hayes ASRC Energy Sevices Co Man justin.hayes@external.eni.com 907-685-0710 Eni representative Mike Grubb ASRC Energy Sevices Co Man michael.grubb@external.eni.com 907-685-0710 Safety Representative Jack Potter ASRC Energy Services HSE Jack.Potter@External.eni.com 970-685-1434 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.95 L80 -3,848.4 10,594.0 3,687.6 10/12/2010 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Slickline 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?N/A Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 10594 835 N/A Casing Collapse Structural Conductor N/A Surface 2,270 Intermediate 4760 Production Liner slotted Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Retrievable Packer 5464' MD /3489' TVD 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Alex Vaughan Giorgio Iannucci Contact Email: alex.vaughan@external.eni.com Contact Phone:907-865-3323 Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Perforation Depth MD (ft): Eni Alaska Well Operations Manager 6283'-10315' 5991 5.5" 3649-3689 9.625" July 3rd, 2023 105944787 4.5" 3688 20" 13.375" 154 2334 154 2183 154 2334 36495991 Proposed Pools: L80 TVD Burst 5456 MD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 355024, 373301, 390616, 391283 210-106 3700 Centerpoint Drive, Ste. 500, Anchorage, AK 99503 50-029-23430-00-00 Eni US Operating Co. Inc. OI11-01 AOGCC USE ONLY slotted Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY Length Size Nikaitchuq Schrader Bluff Oil Pool N/A10594 36883688 Subsequent Form Required: Suspension Expiration Date: 6870 N/A 5,020 approval:Notifyff AOGCC so that a reypresentative may witnessy Sundryrr Number:y BOP Test Mechanical Integrity Test Location Clearancey ons of Approval: ection MIT Req'd? Yes No Subsequent Form Required: Suspension Expiration Date: AOGCC USE ONLY Contact Name: Alex Vaughan Gi i I i Contact Email: alex.vaughan@external.eni.com Contact Phone:907-865-3323 tle:Eni Alaska Well Operations Manager certifyff that the foreygoing is true and the procedure approved herein will not be deviated from without prior written approval. ame and ure with Date: 15. Well Status after proposed work: OIL WINJ WDSPL Suspended GAS WAG GSTOR SPLUG GINJ Op Shutdown Abandoned pproval:Date: resentative: d Date for Operations: July 3rd, 2023 13. Well Class after proposed work: Exploratory Stratigraphic Development Service nts: Proposal Summary Wellbore schematic rations Program BOP Sketch SSSV Type:Packers and SSSV MD (ft) and TVD (ft): ac ker 5464' MD /3489'TVD 5456L804.5"3649-3689 epth MD (ft):Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft):Tubing Size: slottedslotted3688105945.5"4787 364959919.625"5991on 4760iate6870 2,2702183233413.375"2334e 5,020 N/A15415420"154tor N/A ral CollapseBurstTVDMDg Junk (MD): N/A835 Effective Depth TVD:Effective Depth MD:Total Depth TVD (ft):MD (ft): 4 10. Field:Proposed Pools:esignation (Lease Number): 73301, 390616, 391283 8. Well Name and Number: OI11-01 ng: ation or Conservation Order governs well spacing in this pool?N/A Yes No 5. Permit to Drill Number: 6. API Number: 210-106 50-029-23430-00-00 4. Current Well Class: Exploratory Development Stratigraphic Service oint Drive, Ste. 500, Anchorage, AK 99503 ame: ating Co. Inc. quest: Abandon Plug Perforations Fracture Stimulate Reppair Well Operations shutdown Suspend Perforate Other Stimulate Pulll Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alteer Casing Other:Slickline quire a spacing exception due to property boundaries? Current Pools: S ()() PRESENT WELL CONDITION SUMMARY Length Size Nikaitchuq Schrader Bluff Oil Pool /10594 36883688 Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Giorgio Iannucc i June 30th, 2023 By Grace Christianson at 1:09 pm, Jul 10, 2023 323-369 Victoria Loepp 7/7/2023 MDG 7/11/2023 VTL 7/11/2023 X X GCW 07/11/2023 07/12/23 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.07.12 08:14:37 -05'00' RBDMS JSB 071323 3700 Centerpoint Drive Suite 500 Anchorage, Alaska 99503 Giorgio Iannucci Phone (907) 865-3320 Email: Giorgio.iannucci@eni.com June 30th, 2023 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Application for Sundry Approval for OI11-01 Slickline / Eline Intervention Workover Commissioners, ENI US Operating Co. Inc. hereby applies for a Sundry for well OI11-01. OI11-01 was drilled and completed on October 2010 as a water injector. ENI noticed a concern with tubing by inner annulus communication on OI11-01. The IA pressure increased from 33 psi to over 500 psi in a 2-hour period. Injection into the well was shut off and the tubing and IA pressure declined. Injection was reestablished and the IA pressure was bled off and immediately rebounded. The injector was shut in until diagnostics can be conducted. OI11-01 passed its last state witnessed MIT on 03/21/21. Eni is planning to perform a rigless intervention to investigate a potential tubing to annulus hydraulic communication. Please find attached for review commission form 10-403 and supporting documentation. Questions or requests for supplemental information can be directed to: Alex Vaughan, 907-865-3323. Sincerely, Giorgio Iannucci Well Operations Project Manager Sincerely, OI11-01 Workover – Proposal Summary and Wellbore Schematic OI11-01 Slickline/E-line Tubing Leak Diagnostics PTD#:210-106 Status Well OI11-01 is currently shut in waiting for diagnostic work. Scope of Work Eni is planning to perform a rig less intervention on OI11-01 to investigate a potential tubing to annulus hydraulic communication in preparation to define the leak point in the TBG and patch accordingly. General Well Info Reservoir Pressure/TVD: Maximum initial shut-in pressure of approximately 1,610 psi at 3,649’ TVD (0.442 psi/ft static gradient) Wellhead type/pressure rating: Vault, MB-247/5000 psi Well type: Injector Estimated start date: July 3rd, 2023 Intervention Unit: Slickline / Eline Sr. Drilling Engineer: Alex Vaughan alex.vaughan@external.eni.com Work: 907-865-3323 Well Operations Project Manager: Giorgio Iannucci giorgio.iannucci@eni.com Work: 907-865-3320 Procedure Summary 1. Rig up slickline unit over OI11-01. 2. Confirm suspected hydraulic communication between inner annulus and tubing. 3. Establish inner annulus to tubing hydraulic leak rate. 4. Drift to the XN nipple at 5,480’ MD. 5. Perform leak detection diagnostics to generally locate hydraulic communication via slickline conveyed tools between the interval range of 5,480’ MD and surface. 6. Set tubing plug in XN nipple at 5,480’ MD and perform combo (inner annulus and tubing) pressure test 7. Rig down slickline unit. 8. Rig up eline unit. 9. Repeat leak detection diagnostics to precisely locate hydraulic communication via eline conveyed tools across the general interval range identified during previous slickline operations. a. This will include a multi-finger caliper and acoustic leak detection tool. 10. Set the TBG patch at the definitive leak point. a. Off critical path and “cure” the patch as per product procedure by bringing on the well at standard injection rates and temperatures for 24 hours. 11. Rig down eline unit 12. Once patch is cured, perform MITIA to 1650 psi to confirm successful patch installation. State witnessed MIT-IA required after stabilized injection VTL 7/11/23 Current Completion Schematic 13-3/8" 68 ppf Casing, 2,234' MD, 2,183 TVD, 40º Inc 9-5/8" 43.5-47 ppf Intermediate Casing, 5,991' MD, 3,649' TVD, 81º Inc 4-½” 12.6 ppf Production Tubing 5-½” 15.5 ppf Production Liner, 10,594 MD, 3,688' TVD, 89ºInc 3-1/2" 9.2 ppf Inner String, 10,378' MD, 3689' TVD, 91º Inc 3-½” x 5-½” Swell Packers Injection Control Devices AHR Retr. Packer with 2 Feed-Thrus, 5,464 ' MD, 3489 TVD, 67º Inc 4-½” cable clamps Single ¼” Stainless Steel Encapsulated Line with Double End DTS Fiber Confidential MDK 9/03/10 OI11-01 Injector With Fiber/Electric Monitoring Nikaitchuq Field – Oliktok Point Pad Single ¼” Stainless Steel Encapsulated Line for Heel P/T gauge 2133' MD, 2005' TVD, 35º Inc - 4-½” x 1" KBMG GLM, with 2,000 psi A-to-T shear valve 2232' MD, 2084' TVD, 40º Inc - 3.81" X-nipple for possible injection valve 5,480' MD, 3495' TVD, 67 º Inc - 3.725" XN and HAL Mirage Plug with Auto-fill valve 5,450 MD, 3484' TVD, 67º Inc - 3.81" X-nipple VIT, 3 joints, 4-½” x 6", approx 102' As Completed 10/16/10 5,745' MD, 3591' TVD, 72º Inc – Gauge Carrier - for P,T at Heel 5,773' MD, Top Of Liner 5-½” x 8-½” Swell Packers Vetco Gray, MB-247/5000 psi CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: OI11-01 (PTD# 210-106) TxIA Communication Date:Thursday, June 29, 2023 1:40:28 PM Attachments:image002.png image001.png From: Lopez Keith <Keith.Lopez@eni.com> Sent: Thursday, June 29, 2023 12:48 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Hart David <David.Hart@eni.com>; Giraud Hector <Hector.Giraud@eni.com>; Lyden Dan <Dan.Lyden@eni.com>; Dexheimer Stephen <Stephen.Dexheimer@eni.com>; Morgan Michael <Mike.Morgan@eni.com>; Zuber Joshua <Joshua.Zuber@eni.com>; Burgess Larry <Larry.Burgess@eni.com>; Pitzalis Francesco <Francesco.Pitzalis@eni.com>; Brown Timothy <Timothy.Brown@eni.com>; Vaughan Alex <Alex.Vaughan@external.eni.com>; Gueco Chad <Chad.Gueco@external.eni.com>; Iannucci Giorgio <Giorgio.Iannucci@eni.com>; Lopez Keith <Keith.Lopez@eni.com>; Zuber Joshua <Joshua.Zuber@eni.com>; Morgan Michael <Mike.Morgan@eni.com> Subject: OI11-01 (PTD# 210-106) TxIA Communication Mr. Wallace, Early this morning (06-29-23), ENI noticed a concern with tubing by inner annulus communication on OI11-01. The IA pressure increased from 33 psi to over 500 psi in a 2-hour period. Injection into the well was shut off and the tubing and IA pressure declined. Injection was reestablished and the IA pressure was bled off and immediately rebounded. The injector was shut in and will remain shut in until further diagnostics can be conducted with slickline/eline. OI11-01 passed its last state witnessed MIT on 03/21/21. Please let me know of any concerns or further data the AOGCC requires. Thank you. Keith Lopez Senior Production Engineer Eni Petroleum, Alaska 3700 Centerpoint Drive, Suite 500 Anchorage, AK 99503 Direct 907-865-3316 Mobile 907-903-5432 Keith.Lopez@eni.com ------------------------------------------------------------------------------------------------------------------------------------------------------------------- ----- Message for the recipient only, if received in error, please notify the sender and read http://www.eni.com/disclaimer/ MEMORANDUM State of Alaska Pretest 355 - Alaska Oil and Gas Conservation Commission TO: Jim Regg�L P.I.Supervisor �e '1 �i 7�� DATE: Friday, April 2, 2021 SUBJECT: Mechanical Integrity Tests 2101060 " Eni US Operating Company Inc. SPT Oil] -01 FROM: Matt Herrera NDWTCHUQ 011 l AI Petroleum Inspector 1727 _ 1635 - Set: Inspector Reviewed By: BBL Pumped- r��, P.1. Supry y: � NON -CONFIDENTIAL Comm I Well Name MKAITottuQ Oil 1.01 Insp Num: mitMFH210323070501 Rel Insp Num: API Well Number 50-029-23430-00-00 Inspector Name: Matt Herrera Permit Number: 210-106-0 Inspection Date: 3/21/2021 / Packer Well ore -01 Type Inj w TVD Depth 3486 Tubing Pretest 355 - Initial 355 15 Min 30 Min 45 Min 60 Min sss- , - PTD 2101060 " Type Test SPT Test psi 1500 '' IA 5 1727 _ 1635 - 1614 BBL Pumped- 4 BBL Returned: z OA 190 • 230 z0s zoo Interval 4YRTST P/F P ✓ Notes: MIT -IA pressure tested to 1700 PSI per Operations for minimum test pressure ✓ Friday, April 2, 2021 Pagc 1 of I MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission Jim Re ( DATE: Wednesday,December 28,2016 TO: P.I.Supervisor ( l �"�� SUBJECT: Mechanical Integrity Tests ENI US OPERATING CO INC OI11-01 FROM: Jeff Jones NIKAITCHUQ 0111-01 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry J eLi'' NON-CONFIDENTIAL Comm I Well Name NIKAITCHUQ 0111-01 API Well Number 50-029-23430-00-00 Inspector Name: Jeff Jones Permit Number: 210-106-0 Inspection Date: 12/9/2016 Insp Num: mitJJ161212125207 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Tubing o1olTYPe InJwTVD [ 3486 417 416 4I6 416 - PTD 2101060 - jTYpe Test SPT Test psi 1500 IA 1 334 1647 1627 - 1617 Interval4YRTST 1 1P/F _P i OA 210 240 220 - 220 i Notes: 1.1 barrels diesel pumped. 1 well inspected,no exceptions noted. - SCANNED .1 o 5 2.017 Wednesday,December 28,2016 Page 1 of 1 c � > w m cd« •a a • w > > _N N N m C y A C f0 3 0 L' .>. 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O I L 0 d v v ` O z 0, (0 � 1- 00 '0 00 0 00 0 m CL g V O O (00 COO (00 CD CMO E V) E •N N Z Z IA W N Z 1 /�/ 0 O. li N •,- .- e- .- ..- .- v O Lo M M C) M /w _ -) > V Z Z a) W d Z V N w 0 0 CL a Q' Z` h Q O • 7 N O J a `0 '5 = m 0 o U O U U U U U 0 0 y m E c a u N_ lii O E N N N N N N In U) N U ' 0 J Qto 0 a N `O v . I— 4 o N `O CO ..- N O W Q O '. II, it j 0 c O Si V Qo I— a) Z 0 0 0 0 Q d 0 m ..... m E 0 v v > > 16 >> o> > Z W m m W W 1 a) 0 o co o 0 o c c c c c • O) i J J J J J J a a a a a) C 00 ;v v v v v v E E E E E 1I M 2 2 2 2 2 2 U U U a) U E z c N I m N mf . d G >E a F. N a v rn N Z y o ce Lo O a • 1 \ \ O U I U T E i l a l a) 10 O O O O O O O a n O y D OO t C a) O O a J J J J J J J J W d' J 3 ___ Q > U Q CC i U U MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Re DATE:Tuesday,May 24,2011 P.I.Supervisor j� 5I�5( SUBJECT:Mechanical Integrity Tests ENI US OPERATING CO INC 0111-01 FROM: Matt Herrera NIKAITCHUQ 0111-01 Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprv<1.&.1.-- NON-CONFIDENTIAL Comm Well Name: NIKAITCHUQ 011 1-0 1 API Well Number: 50-029-23430-00-00 Inspector Name: Matt Herrera Insp Num: mitMFH110517200143 Permit Number: 210-106-0 Inspection Date: 5/17/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well TIo111-oifType Inj. W j TVD ' 3486 IA 20 2510 ' 2450 2440 . 2440 , P.T.D 2101060 1TypeTest LSPT Test psi 1500 OA 200 — 320 245 230 225 j Interval INITAL P/F P Tubing 372 373 373 373 373 — Notes: Initial MIT performed.Test pressure taken to 2500 psi due to lack of well schematic with packer TVD to determine minimum test pressure Tuesday,May 24,2011 Page 1 of 1 Page 1 of 1 Regg, James B (DOA) 2-10- /Cc> From: Lockhart Brent[Brent.Lockhart@enipetroleum.com] Sent: Thursday, January 20, 2011 11:07 AM 11 To: Regg, James B (DOA); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (DOA); Maunder, Thomas E (DOA) Cc: Schwartz, Guy L (DOA); Brink Jason Subject: Pre Injection MIT for Eni 0111-01 Attachments: Eni 0111-01 10-426.xls; 0111-01 Pre Injection MIT Chart.pdf; 0111-01 Pre Injection MIT Chart sig.pdf Jim, Please find attached the appropriate paperwork for the pre-injection MIT on 0111-01. If you have any questions, please let me know Brent Lockhart Sr. Production Engineer Eni Petroleum -Alaska 907 865 3339 Message for the recipient only, if received in error, please notify the sender and read http://www.eni.it/disclaimer/ This message may contain information that is confidential, and is being sent exclusively to the Recipient. If you are not the designated Recipient, you are prohibited from utilizing, copying or divulging the information contained in this message,or taking any action whatsoever on the basis of the information herein. If you have received this message by mistake, we ask you to kindly inform the Sender and to delete the message. It is understood that, with regard to messages sent by its network, the Company is not responsible for any statements made or opinions expressed, that are not strictly related to the Company's operations. 1/20/2011 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.regg(rilalaska.aov; doa.aoocc.prudhoe.bavaalaska.gov; phoebe.brooks(cialaska.00v; tom.maunderc(D.alaska.00v OPERATOR: Eni US Operating Co Ince> ` , M1( FIELD 1 UNIT/PAD: Nikiatchuq Field/Oliktok Point Pad 1" ( I DATE: 10/17/10 OPERATOR REP: Jack Keener AOGCC REP: N/A Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 0111-01 " Type Inj. W TVD '3,486' Tubing 1,500 '1,900 '1,900 1,900 Interval 1 P.T.D. 210-106 ./ Type test P Test psi "1 500 Casing 200 2,500 2,500 2,500 P/F P Notes: Pre Injection MIT OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing. P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. _ Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D=Drilling Waste M=Annulus Monitoring I=Initial Test G=Gas P=Standard Pressure Test 4=Four Year Cycle I=Industrial Wastewater R=Internal Radioactive Tracer Survey V=Required by Variance N=Not Injecting A=Temperature Anomaly Survey T=Test during Workover W=Water D=Differential Temperature Test 0=Other(describe in notes) Form 10-426(Revised 06/2010) 2010-1017 MIT_Nikaitchuq_0111-01.xIs 1 HR ._ 30 M. _ D._ .k. ..lori'firrMile_,.... .ris iv. °1%. MirAillilw4 I a_,,,,,,_...--------_______=._a.•,.......,a../---------•.w. , w.... . .•...1.„„..._==.1. 4.,4,_4•14,„, 0-4•• •••-mi____".....,......-4......,...„ ooN• . 0- . , 11 ,0„,„_=_IIII,.. .1,1,„4,000; „„,_,,,=4„,...„4„,.. . 0,0 i aw...,==_=...__,,,,%„,„„_ e \ ‘ ce.--__. � � � ps ,.......=,,,vop Origareallft 00 OfirmenraiStr Ot. \ \,, / 0141.11=1140 4% o// .. _ •__ ....:_- i ft/ 0011 Use ier IOSIONE 000 . . 1 Il' ,I ,p � ��'� K T SEC * t�`,,` ��`rsso r r.,r Z ill I''J �, I p 1J,, * .#### Q X y�� ,� � ,`�i,��:13 �i��G,� 3 1111111111111111111111 111111111W .■■■1itilil��rr� 11� J §1.1411"11111111111".'44111111• I� IMO Uniatiggik .,., ��o 842) ilk ��1'�� ,,�qiiivireptil vo.. 7_,000.0 , 'Los \ ..._.... * • 4:b..... tertilh"Orght'st I +0.14,72.0 4*.saiimos i it glitt ,It 4 i ' .4:0. ..zok.... . 41.....1=0-0.4 44ryse. 0A:, - / //toliv / 400„graroiroti 4 ,i, ? 1 t 1 _4„,„mori: 4 ` ` ♦ '��. _-,ter-�■ ems.►/�/ / ' ///// ,,/ 1 ` O�� fir:�� ti�/ / / / i,e/- 4,411,4 ,4„,zzir _ •;.`•mow�.��..��/�/ *4 V*rilx44417,Wil, raa.""-/l ■14,111:1:444010.71:1, 0.414.4, 41:11 , W11%,•., /. 1111111111111•W44km 1 ma.... wirr Znale.„1 .0111W.M 1 w s��"W- l 'W 0£ __ IIH L 42) „ H Page 1of� ' / /G /1 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Wednesday, January 12, 2011 3:53 PM To: 'Lockhart Brent'; 'Brink Jason' Cc: Maunder, Thomas E (DOA) Subject: FW: Injection Well As follow-up to 0111-01 I don't have the LWD sonic log or USIT that was run for cement evaluation. We have the OH resistivity logs only. I need these to evaluate the wellbore for UIC compliance. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Schwartz, Guy L (DOA) Sent: Wednesday, January 12, 2011 2:38 PM To: 'Lockhart Brent' Cc: Maunder, Thomas E (DOA); Regg, James B (DOA) (jim.regg @alaska.gov) Subject: RE: Injection Well Brett, I can't answer the question regarding the 10 day notice ... defer to Tom or Jim. As far as the MIT on 0111-01 .. it will need to be done after the well is on injection and temperatures are stable before a witnessed MIT test is done. The initial rig MIT-IA is normally sufficient for startup puposes.... Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Lockhart Brent [mailto:Brent.Lockhart@enipetroleum.com] Sent: Wednesday,January 12, 2011 2:23 PM To: Schwartz, Guy L (DOA) Subject: Injection Well Guy, Two questions about our upcoming injection at Nikaitchuq. The regulations state that I am supposed to give the commission 10 day notice prior to water injection. Can I give 10 day notice prior to approval of our Area Injection Order(AIO)? If so, I would like to give 10 day notice for our first injection well, 0111-01. Can I schedule the pre injection MIT on OI11-01 prior to approval of our AIO? Thanks for your help.... Brent Lockhart Sr. Production Engineer Eni Petroleum -Alaska 907 865 3339 1/12/2011 STATE OF ALASKA ALASK JIL AND GAS CONSERVATION COMMIz,-.ON WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil❑ Gas❑ Plugged❑ Abandoned ❑ Suspended ❑ lb.Well Class: 20AAC 25.105 20AAC 25.110 Developmen • (l Exploratory❑ GINJ❑ WINJ PI WDSPL❑ WAG❑ Other❑ No.of Completions: Service [ J' v `�1s'Stratigraphic Test❑ 2. Operator Name: 5. Date Comp.,Susp., or 12. Permit to Drill Number: ENI US Operating Co Inc Aband.: 10/17/2010 - 210-106 3.Address: 6. Date Spudded: 13.API Number: 3800 Centerpoint Drive Suite 300,Anchorage 99503 9/22/2010 50-029-23430-00-00 ' 4a. Location of Well(Governmental Section): 7. Date TD Reached: 14,Well Name and Number: Surface: 3186.2 FSL 1597.2 FEL S5 T13N R9E UM • 10/8/2010 0111-01 Top of Productive Horizon: 8. KB(ft above MSL): '1•253:115. Field/Pool(s): 1730'FSL, 2869'FEL,S32 T14N R9E UM Ground(ft MSL): 12 Nikaitchuq . Total Depth: 9. Plug Back Depth(MD+TVD): 4934 FSL 572 FEL 31 T14N R9EUM ' 10594 MD/3689 TVD 4b. Location of Well(State Base Plane Coordinates, NAD 27): 10.Total Depth(MD+TVD): 16. Property Designation: • Surface: x- 516682.79 • y-6036539.39 • Zone- 4 • 10594 MD/3689 TVD • 355024, 373301, 390616,391283 TPI: x- 515390.801 y-6040359.043 Zone- 4 11.SSSV Depth(MD+TVD): 17. Land Use Permit: Total Depth: x- 512390.94 y-6043558.1 Zone- 4 none ADL 417493 18. Directional Survey: Yes U No ❑ 19.Water Depth, if Offshore: 20.Thickness of Permafrost(TVD): (Submit electronic and printed information per 20 AAC 25.050) (ft MSL) J&54 1'77C /43 ;.2 4'- r/ 21. Logs Obtained(List all logs here and submit electronic and printed information per 20 AAC 25.071): GR/RES/Sonic. 22. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD FT PULLED 20" 178.89 X-65 SURFACE 154 SURFACE 154 30 Cement to Surface 13-3/8" 68 L-80 SURFACE 2334 SURFACE 2160 16 533 bbls 10.7#ASL,70 bbls 12#Crete 9-5/8" 47 L-80 SURFACE 5990 SURFACE 3653 12.25 211 bbls 12.5#Deeperete 5.5" 17 L-80 5807 10594 3606 3689 8.5 slotted liner 23.Open to production or injection? Yes al No❑ If Yes, list each 24. TUBING RECORD interval open(MD+TVD of Top&Bottom; Perforation Size and Number): SIZE DEPTH SET(MD) PACKER SET(MD) slotted liner with 3-1/2"inner string inside for water 3.5 5456 5456 injection distribution. MITIA to 2500 PSI. 25. ACID,FRACTURE,CEMENT SQUEEZE, ETC. ;0`r':--.'`124 t DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED _ ' 9.1 r it '1,11 26. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: NA NA Test Period -► Flow Tubing 'Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 24-Hour Rate -► 27. CORE DATA Conventional Core(s)Acquired? Yes ❑ No E ' Sidewall Cores Acquired? Yes ❑ No 0 If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. NOV 2 9 2010 RBDMS NOV 3 0 z1 + lima s„. {a S Coif .W u' j Form 10-407 Revised 2/2007 CONTINUED ON REVERSE ',Q� Anchorage �( 6 28. GEOLOGIC MARKERS (List all formations and markers encountered): 29. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes n No If yes, list intervals and formations tested, briefly summarizing test results.Attach separate sheets to this form, if Permafrost-Top surf surf needed, and submit detailed test information per 20 MC 25.071. Permafrost-Base 1854 1770 5 yo 3 �TL/ S/tNG (r OA sand top 5874 3626 Formation at total depth: OA sand 10594 3687 30. List of Attachments: Summary of Daily ops, Directional survey,wellbore schematic 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jason Brink @ 907-865-3321 Printed Name: Maurizio Grandi Title: Well Operation Project Manager Signature: 11/" Phone: Date: 11/2 7/1 INSTRUCTIONS IITIA to 2500 PSI. This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole Item 1 a: Classification of Service wells: Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other. Multiple completion is defined as a well producing from more than one pool with prod Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional in Item 26: Method of Operation: Flowing,Gas Lift, Rod Pump, Hydraulic Pump, Submersible,Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 2/2007 i r"` ? Eni E&P Division Report Well Name:on,-01 OR ENI Petroleum Co.Inc. Daily Repo Well Code:25056 Field Name:Nikatchuq Date:9/19/2010 - Report#: 1 APlnm^: page 1 of 1 Wellbore name: 0111-01 Well Header 402100 Concession N° I ENI PETROLEUM IENI Share(%) 100.001 HyORIZONTAL Configuration type Rotary Table Elevation(ft) Ground Level(ft) 'Water Depth(ft) RKB-Base Flange(ft) IRKB-Tubing Spool(It) 53.25. 12.20 0.00 Rig Information Contractor I Rig Name 'Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore I Job Phase Spud Date 'Target Depth(ftKB) 'Target Depth(TVD..'Depth Dr.(MD)(ft) Drilling Hours(hr) !Avg ROP(ft/hr) IDFS(days) 0111-01 DRILLING 9/22/2010 10,521.0 11,010.00 131.24 83.9 -2.15 Daily Information End Depth(RKB) End Depth(ND)(f..I Depth Progress(ft) 'Drilling Hours(hr) 'Avg ROP(ft/hr) I POB I Temperature(°F) Weather I Wind 0.0 79.01 34.9 Overcast.WC 28° 1°N(Q 8.4 mph Daily summary operation 24h Summary Released rig from well OP05-06 a 1800 hrs.\Prep rig 8 location for move to well 0111-01. Operation at 07.00 Rig move to well 0111-01. 24h Forecast Move and R/U Nabors 245E on well 0111-01 •Lithology 'Shows MAASP Pressure(psi) 'Mud Weight(lb/gal) Time Log - Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. _ Act. Plan Oper.Descr. 18:00 00:00 - 6.00' 6.00 MOB A 2 P Prep location 8 rig to move from well OP05-06 to well 0111-01\Cut out section in stand pipe 8 weld in 1002 union for future balance drilling system. Daily Contacts Position Contact Name Company Title E-mall Office Mobil Eni representative Jack Keener Eni Petroleum Sr.Drlg.Spvr. Jack.Keener@enipetroleum.com 907-670-8623 '907-715-6434 Eni representative David Smith Eni Petroleum Drlg.Spvr. 907-670-8623 907-632-3058 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-670-8607 907-575-9427 Eni representative Pete Adams Eni Petroleum HSE 907-685-1227 907-440-0806 Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-8539 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date Last Leakoff Test Depth(ftKB) 'ND(ftKB) I Fluid Type 'Fluid Density(lb/gal) IP Surf Applied(psi) I Eq.Mud Weight(1b/gall I Leak Off Pressure(psi) • • o } Eni E&P Division (Well Name:0111-01 OR ENI Petroleum Co.Inc. Daily Report Well Code:25056 Field Name:Nikatchuq Date:9/20/2010 - Report#: 2 Ar'uLtwl: page 1 of 1 Wellbore name: 0111-01 Well Header 4D 0oConeession N• I ENI PETROLEUM IENI Share(%) 100.001 HORIZONTAL NTALatlon type Rotary Table Elevation(ft) I Ground Level(ft) [Water Depth(ft) RKB-Base Flange(ft) 'RKB-Tubing Spool(ft) 53.25 12.20 0,00 Rig Information Contractor 'Rig Name I Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore \Job Phase (Spud Date 'Target Depth(ftKB) 'Target Depth(TVD...I Depth Dr.(MD)(ft) I Drilling Hours(hr) Avg ROP(ft/hr) I DFS(days) 0111-01 DRILLING 9/22/2010 10,521.0 11,010.00 131.24 83.9 -1.15 Daily Information End Depth(ftKB) End Depth(ND)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(Mr) POB Temperature(•F) Weather Wind 0.0 79.0 31.8 Cloudy.WC 23.9° 333°NNW(§9.2 mph Daily summary operation 24h Summary Prep to move rig&utility modules\Move utility module&rig off OP05-06\Remove mats&Herculite liner\Lay down new Herculite and spot matting boards\Move rig&utility modules onto 0111-01 conductor\Hook-up interconnects&berm rig and utility modules\Install starting head&drilling riser per Vetco Gray Rep.(test to 500 psi).-Hook-up flow line./Spot drip pan for MI Swaco CCB unit. Operation at 07.00 Load pipe shed&R/U MI Swaco CCB unit. 24h Forecast X-ray stand pipe\R/U COB unit 1 Load pipe shed&P/U 5"drill pipe to drill intermediate hole section\Mix spud mud\Conduct Pre-spud meeting for Well 0111-01\P/U BHA#1 Lithology 'Shows IMAASP Pressure(psi) I Mud Weight(lb/gal) Time Log Start End Cum Time Time Dur(hi) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 03:00 3.00' 3.00 MOB A 2 P Prep for rig move\Finish blow down&disconnect of service lines between modules\Install new spacer section in stand pipe for ECD unit.\Warm up Lampson units for move 03:00 06:00 3.00 6.00 MOB A 2 'P Held PJSM-Jack up and move utility module from rig sub.\Move rig sub off well OP05-06-Finish installing stand pipe. 06:00 10:30 4.50 10.50 MOB A '2 'P Remove rig mats&Herculite(cut&fold-up in 25'025'section for reuse)\Dress spots on pad. Lay out new Herculite and mats for well 0111-01 10:30 16:00 5.50 16,00 MOB A 2 'P Move rig sub over 0111-01 and set in place\Move utility module.Spot&set in place. 16:00 20:00 4.00' 20.00 MOB A '2 'P Hook-up interconnects between rig&utility modules and berm around modules\Steam and water operational. 20:00 00:00 4.00 24.00 MOB A '2 'P Install starting head and drifting riser with Vetco Gray Rep.Test to 500 psi.\Hook-up flow line.Spot drip pan to R/U MI Swaco CCB unit. Daily Contacts Position Contact Name Company Title E-mail _ Office Mobile Eni representative Jack Keener Eni Petroleum Sr.Ddg.Spvr. Jack.Keener(rDenipetroleum.com 907-670-8623 '907-715-6434 Eni representative David Smith Eni Petroleum Orig.Spvr. 907-670-8623 907-632-3058 ✓ Eni representative Bemie Leas Eni Petroleum Rig Clerk 907-670-8607 907-575-9427 Eni representative Pete Adams Eni Petroleum HSE 907-685-1227 907-440-0806 Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-8539 Last Casing seat Cas.Type OD(In) ID(in) Grade Top(RKB) Bottom(ftKB) Run Date Last Leakoff Test Depth(RKB) 'ND(ftKB) I Fluid Type 'Fluid Density(Iblgal) I P Surf Applied(psi) I Eq.Mud Weight(1b/gall Leak Off Pressure(psi) ri* Eni E&P Division Name:0111-01 OR ENI Petroleum Co.Inc. Daily Report Well Code:25056 Field Name:Nikatchuq • en II n Date:9/21/2010 - Report#: 3 APIIUWI page 1 of 1 Wellbore name: 0111-01 Well Header Permit/Concession N' !Operator I ENI Share(%) 100.00[Well OR ZONTAL tion type 402100 ENI PETROLEUM Rotary Table Elevation(ft) !Ground Level(ft) I Water Depth(ft) RKB-Base Flange(ft) I RKB-Tubing Spool(ft) 53.25 12.20 0.00 Rig Information Contractor Rig Name I Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase I Spud Date !Target Depth(ftKB) !Target Depth(TVD..IDepth Dr.(MD)(ft) Drilling Hours(hr) !Avg ROP(fl/br) I DFS(days) 0111-01 DRILLING 9/22/2010 10,521.0 11,010.00 131.24 83.9 -0.15 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Grilling Hours(hr) Avg ROP(ft/hr) POB Temperature('F) Weather Wind 0.0 89.0 30.4 Partly Cloudy.WC 19°NNE @ 11.4 21° mph Daily summary operation 24h Summary R/U MI Swaco CCB units,R-valve conex and hook-up lines\Load pipe shed with 5"drill pipet X-ray&hydro test stand pipe to 4700 psi.for 15 mins.\Inspect Top Drive\Calibrate&test LEL&H2S sensors\MI Swaco R/U CCB lines I P/U 5"drill pipe(6126')and 5"HWDP(3761\MI Swaco test CCB lines\Calibrate block height f/Schlumberger&Canrig mud loggers I Load floor w/BHA#1&#2. Operation at 07.00 Working spud clean out BHA. 24h Forecast P/U BHA#1\PJSM\Clean out conductor to 160'\POOH&P/U SBL/Gyro Data BHA#2\Hold pre-spud meeting\Spud well and drill ahead as per Eni well plan. Lithology 'Shows MAASP Pressure(psi) I Mud Weight(Ib/gal) 8.70 Time Log Start End Cum Time Time Dur.(hr) Dur(hr) Phase Opr. Act. Plan Opera Dew.' 00:00 11:30 11.50 11.50 MOB A 1 'P R/U&install Katch-up&berm around rig\X-ray welds on stand pipe\Spot drip pan\Load pipe shed vi 192 jts.dnt pipe\ Hydro test stand pipe 1/4700 psi.f/15 minutes\Break down scaffolding&remove from floor I Inspect Top drive(change oil)\ Calibrate&test LEL&H2S sensors\MI Swaco R/U CCB lines to rig. 11:30 18:00 '' 6.50 18.00 MOB E 4 P P/U 5"drill pipe in mouse hole&rack in derrick-113800'.1 R/U MI Swaco CCB lines. 18:00 18:30 0.50 18.50 MOB E 25 P Service rig equipment. 18:30 21:30 3.00 21.50 MOB E 4 P P/U 5"drill pipe in mouse hole&rack in derick(/3800'-1/6126'. 21:30 22.30 1.00 22.50 MOB E 4 P P/U 5"HWDP(4 stands)in mouse hole&rack in derrick-1/367' 22:30 00:00 1,50 24.00 MOB E 1 P Calibrate block height f/Schlumberger&Canng\Clean floor&load same with BHA components for BHA's#1&#2 I MI Swaco test CCB lines. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener Eni Petroleum Sr.Dig.Spvr. Jack.Keener©enipetroleum.com '907-670-8623 907-715-6434 EN representative David Smith Eni Petroleum Dag.Spvr. 907-670-8623 907-632-3058 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-670-8607 907-575-9427 Eni representative Pete Adams Eni Petroleum HSE 907-685-1227 907-440-0806 Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-8539 Last Casing seat Cas.Type I OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date 1 Last Leakoff Test Depth(RKB) I TVD(ftKB) [Fluid Type !Fluid Density(lb/gal) IP Surf Applied(psi) I Eq.Mud Weight(lb/gal) I Leak Off Pressure(psi) , VI ifilhil Eni E&P Division !Well Name:0111-01 OR ENI Petroleum Co.Inc. Daily Report Well Code:25056 Field Name:Nikatchuq • Date:9/22/2010 - Report#: 4 API/UWI �" " page 1 of 1 Wellbore name: 0111-01 Well Header Pennit/Concession N° I Operator I ENI Share)%) 'Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) [Ground Level(ft) 'Water Depth(ft) I RKB-Base Flange(ft) IRKS-Tubing Spool(ft) 53.25 12.20 0.00 Rig Information Contractor I Rig Name Rig Type NABORS ALASKA NABORS 245 E !LAND RIG Job Information Wellbore Job Phase ISpud Date 'Target Depth(ftKB) [Target Depth(TVD...IDepth Dr.(MD)(ft) Drilling Hours(hr) !Avg ROP(ft/hr) I DFS(days) 0111-01 DRILLING 1 9/22/2010 10,521.0 11,010.00 131.24 83.9 0.85 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 777.0 776.1 655.00 9.03 72.5 89.0 29.7 Partly Cloudy.WC 15°NNE©3.6 mph 26.2° Daily summary operation 24h Summary ' P/U BHA#1 1 Tag©122'w/5K-Rotary drill f/122'-t/160'1 POOH w/BHA#1-M/U BHA#2 as per Schlumberger DD/MWD&Gyro Data\Drill f/160'4/342'survey as needed\POOH&P/U remaining BHA(NM Flex DC-Jars-HWDP)\Drill Slide/Rotate f/342'-1/777'as per Schlumberger DD.Survey with Gyro Data as needed. Operation at 07.00 Drill Slide/Rotary ahead as per Schlumberger DD-Gyro Data survey every 90'or as needed. 24h Forecast Drill slide/Rotary ahead to 13 3/8"csg TD li 2356'. Lithology 'Shows MAASP Pressure(psi) I Mud Weight(Iblgal) 8.90 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 02:30 2.50 2.50 DRILL E 4 P P/U&M/U BHA#1 as per Schlumberger DD-clean out assembly. ' 02:30 03:30 1.00 3.50 DRILL E 1 P Held PJSM with all personnel\Fig stack&break circulation-No leaks I Test mud line to 3300 psi. 03:30 05:00 1.50 5.00 DRILL E 3 P RIH tag 08 122'vd 5K-Drill f/122'-5160'pump rate 360 gpm(fg 312 psi.135 rpm©1.5K torque 16-8K WOB 1 Up wt= 70K,On wt.=70K,Rot wt.=70K.ART=0.75 hrs. 05:00 07:30 2.50 7.50 DRILL E 4 P POOH w/BHA#'1-M/U BHA#2 as per Schlumberger DD/MWD.P/U NM Stab-NM XO-Gyro Pulse tool-Power Pulse MWD-ACR 625-UBNO-NM Stab\Orientation of Gyro Data tool. 11/ 07:30 08:00 0.50 8.00 DRILL E 1 P Held Pre-Spud meeting with all personnel-Discussed Well plan,well control&rig evacuation,spill awareness,hole cleaning. 08:00 11:30 3.50 11.50 DRILL E 2 P Drill 1/160'-5342'pump rate 500 gpm©700 psi./35 rpm @ 1.5K torque 110-20K WOB\Up wt.=75K,Dn wt.=75K,Rot wt.=75K.ART=1.4 hrs. 11:30 13:30 2.00 13.50 DRILL E 4 P POOH f/342'-5154'wy BHA#2\P/U two NM Flex DC,jars&two joints HWDP as per Schlumberger DD. 13.30 00:00 10.50 24.00 DRILL E 3 P Drill Slide/Rotate 1/342'-5777'(731'TVD)-pump rate 515 gpm©775 psi.-40 rpm©2-3K f/Ibs torque 115-20K WOB 1 Up wt.=90K-Dn wt=90K-Rot wt.=92K.ART=1.29 hrs.1 AST=4.84 hrs. Total ADT=8.28 hrs. Total ART=4.84 Total AST=3.44 1 Total Jar=8.28 hrs. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener Eni Petroleum Sr.Drig.Spvr, Jack,Keener@enipetroleum.com 907-670-8623 907-715.6434 Eni representative David Smith Eni Petroleum Drig.Spur. 907-670-8623 907-632-3058 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-670-8607 907-575-9427 Eni representative Pete Adams Eni Petroleum HSE 907-685-1227 907-440-0806 • Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-8539 Last Casing seat - Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date • Last Leakoff Test Depth(ftKB) [TVD(ftKB) 'Fluid Type I Fluid Density(Iblgal) 'P Surf Applied(psi) I Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) • tillifilil Eni E&P Division Ewen Name:0111-01 i-01 OR ENI Petroleum Co.Inc. Daily Report Well Code:25056 Field Name:Nikatchuq et(� Date:9/23/2010 • Report#: 5 APINwh I t' " page 1 of 1 Wellbore name: 0111-01 Well Header • 402100 Concession N• IENI PETROLEUM IENI Share(%) 100.001 HORIZONTALation type Rotary Table Elevation(ft) 'Ground Level(ft) 'Water Depth(ft) 'RKB-Base Flange(It) I RKB-Tubing Spool(ft) 53.25 12.20 0.00 Rig Information Contractor Rig Name I Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase I Spud Date 'Target Depth(ftKB) 'Target Depth(TVD..]Depth Dr.(MD)(ft) 'Drilling Hours(hr) Avg ROP(ft/hr) I DFS(days) 0111-01 DRILLING 9/22/2010 J 10,521.0 11,010.00 131.24 83.9 1.85 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(•F) Weather Wind 2,311.0 2,142.8 1,534.00 15.27 100.5 91.0 29.7 Partly Cloudy.WC 88°E(oj 3.9 mph 25.2° Daily summary operation 24h Summary Drill Slide/Rotate(/777'-112311'as per Schlumberger DQ.\S yew with Gyro Data 1/1309'.1 Plan to T/D fol 2347' Operation at 07.00 POOH-backreaming to HWDP. 24h Forecast T/D well a 2347'I Circulate bottoms-up 3X(pump weighted sweep)-Reciprocate Z.backream pipe 1 POOH-Backream to HWDP I RIH to T/D\Circulate clean I POOH&L/D BHA#2 1 Perform dummy run w113 3l8"hanger I R/U GBR&run 13 3/8"cog. Lithology 'Shows MAASP Pressure(psi) I Mud Weight(lb/gal) 9.20 Time Log Start End Cum Time _ Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 12:00 12.00 12.00 DRILL E 3 P Drill Slide/Rotate 1/777-111500'(1453'TVD)-pump rate 600 gpm @ 1220 psi,-40 rpm @ 2-4K ftAbs torque 120K WOB 1 Up wt.=105K-On wt=90K-Rot wt.=100K,ART=1.6 hrs.1 AST=5.35 hrs.\Mud wt.9.2 ppg 1 ECD=9.68 ppg. 1200 '18,00 6.00 18.00 DRILL E 3 P -Drill Slide/Rotate 1/1500'-1/1915'(1755'TVD)-pump rate 610 gpm CZ 1250 psi.-40 rpm @ 3-4K ftAbs torque 120K WOB 1 Up wt.=110K-Dn wt.=100K-Rot wt.=105K.ART=1.05 hrs.1 AST=3.26 hrs.\Mud wt.9.2 ppg.I ECD=9.55 ppg. 18:00 "00:00 ' 6.00 24.00 DRILL E 3 P Drill Slide/Rotate t/1915'-1/2311'(2088'TVD)-pump rate 750 gpm @ 1620 psi.-40 rpm @ 3.2-4.9K Nibs torque 120K WOB\Up wt.=120K-Dn wt=105K-Rot w1.=112K.ART=1.15 hrs.\AST=2.86 1 Mud wt.9.2 ppg.1 ECD=9.91 ppg. Total ADT=23.55 hrs. Total ART=7.24 hrs. Total AST=16.31 hrs. Total Jar=23.55 hrs. • • Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative -Jack Keener Eni Petroleum Sr.Dig.Spur. Jack.Keener(@enipetroleum.com 907-670-8623 907-715-6434 Eni representative David Smith Eni Petroleum Drlg.Spur. 907-670-8623 907-632-3058 Eni representative Bemie Leas Eni Petroleum Rig Clerk 907-670-8607 907-575-9427 Eni representative Pete Adams Eni Petroleum HSE 907-685-1227 907-440-0806 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-8539 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 13 3/8 8.540 LBO 0.0 2,334.7 9/24/2010 Last Leakoff Test Depth(ftKB) ITVD(ftKB) Fluid Type 'Fluid Density(lb/gal) 1P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) IR* Eni E&P Division Name:0111-01 OR ENI Petroleum Co.Inc. Daily Report Well Code:25056 Field Name:Nikatchuq • � 3 Date:9/24/2010 - Report#: 6 API/UWI: "- page 1 of 1 Wellbore name: 0111-01 Well Header Pe 402100 iConcession N' 'Operator PEoROLEUM I ENI Share(%) 100.00'Well HOR ZONTAL Configuration type Rotary Table Elevation(ft) Ground Level(ft) 'Water Depth(ft) RKB-Base Flange(ft) I RKB-Tubing Spool(ft) 53.25 12.20 0.00 Rig Information Contractor I Rig Name 'Rig Type NABORS ALASKA `NABORS 245 E LAND RIG Job Information Wellbore I Job Phase Spud Date 'Target Depth(ftKB) !Target Depth(TVD...I Depth Dr.(MD)(ft) Drilling Hours(hr) 'Avg ROP(ft/hr) I DFS(days) 0111-01 DRILLING 9/22/2010 10,521.0 11,010.00 131.24 83.9 2.85 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature('F) Weather Wind 2,347.0 2,169.5 36.00 0.48 75.0 91.0 30.9 Light Snow.WC 18° 290°WNW(g 21.4 mph Daily summary operation 24h Summary ROTARY DRILLED FROM 2,311'TO 2,347'MD TD SURFACE HOLE. CIRCULATED HOLE CLEAN. BACKREAM FROM 2,347'TO 684'. TRIPPED IN HOLE FROM 684'TO 2,347'. CIRCULATED BOTOMS UP 3X. POOH ON ELEVATORS TO 216'. RACK BACK 18 SIDS OF DRILL PIPE IN DERRICK. LAY DOWN BHA AS PER SLB DIRECTIONAL DRILLER. MAKE DUMMY RUN WITH HANGER. MU SHOE AND FLOAT. CHECK FLOATS. RIH TO 590'WITH 13-3/8"CASING. Operation at 07.00 CIRCULATING AND CONDITIONING HOLE FOR 13-3/8"CEMENT JOB. 24h Forecast CIRCULATE AND CONDITION HOLE FOR CEMENT JOB.CEMENT 13-3/8"CASING.NIPPLE UP AND TEST BOPE. P/U BHA#3 AND DRILL INTERMEDIATE HOLE. Lithology I Shows MAASP Pressure(psi) I Mud Weight(Iblgal) 9.30 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 00:30 0.50 0.50 DRILL E 3 P ROTARY DRILLING FROM 2,311'to 2,347. UP WT=125 DN WT=100 ROT-112. WOB; 20K GPM=650 PSI=1350/1480 ECD=9.78 MW=9.2 ART=0 AST=0,48 ADT=0.48 JAR HOURS=21.90 00,30 02:30 2.00 2.50 DRILL E 7 P CIRCULATE AND CONDITION.CBU. PUMP 25 BBLS 10.8 PPG WEIGHTED SWEEP. BACK REAM AND SLIDE DOWN. GPM=800 PSI=1,670 RPM=60 TO=3,600. BACK PUMPS DN TO 500 GPM ON DN STROKE. SWEEP BACK 600 STROKES OVER. 50%MORE CUTTINGS WITH SWEEP. MONITOR WELL FOR 10 MINS. 02:30 08:00 5.50 8.00 DRILL E 4 P BACKREAMING FROM 2,347'TO 684', GPM=800 PSI=1,670 TO=4,600 UP DN 110 ROT=110. SLM OUT-NO CORRECTION.TO INCREASED TO 3-8 FROM 1,860'10 1,834'. 08:00 09:00 1.00 9.00 DRILL E 7 P CIRCULATE AND CONDITION UNTIL HOLE IS CLEAN.BACK REAM UP. GPM=600 PSI=930 RPM=60 UP WT= 90 ROT WT=90 TO=1,000. NO PUMPS OR ROTATING WHEN GOING DOWN TO KEEP FROM SIDETRACKING THE WELL. 09:00 10:00 1.00 10.00 DRILL E 4 P RIH FROM 684'TO 2,347'. UP WT=115 DN WT=90 NO PROBLEMS. NO FILL ON BOTTOM. 10:00 12:00 2.00 12.00 DRILL E 7 P CIRCULATE AND CONDITION. PUMP 30 BBL 10.8 PPG SWEEP. CBU 3X. GHPM=800 PSI=1,730 RPM=60 TO =3900 UP=110 SDN=100 ROT=110. BACK REAM UP. BACK PUMP OFF TO 600 GPM ON DOWN STROKE.PSI =1,060.NO NOTICABLE CHANGE IN CUTTINGS WITH SWEEP. 12:00 16:00 4.00 16.00 DRILL E 4 P POOH FROM 2,347'TO 216'. 18 STDS OF DRILL PIPE IN DERRICK/5 STDS HWDP WITH JARS. RACK BACK 1 STD OF COLLARS. NO NOTICEABLE DRAG. UP=130 DN=90. 16:00 19:00 3.00 19,00 DRILL E 4 'P LAY DOWN BHA AS PER SLB DIRECTIONAL DRILLER. 19:00 22:00 3.00 22.00 DRILL G 1 P RIG UP TO RUN CASING. DO DUMMY RUN WITH HANGER. 22:00 00:00 2.00 24.00 DRILL G 4 P MU SHOE AND FLOAT. CHECK FLOATS. RIH TO 590'W/13-3/8"CASING..80K DN. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener Eni Petroleum Sr.DrIg.Spvr. Jack.Keenercenipetroleum.com 907-670-8623 907-715-6434 • Eni representative Gary Goedich Eni Petroleum Ddg.Spvr. 907-670-8623 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-670-8607 907.575-9427 Eni representative Jack Potter Eni Petroleum HSE 907-685-1227 907-632-2236 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-8539 Last Casing seat Cas.Type I OD(in) ID(in) Grade Top(RKB) Bottom(ftKB) Run Date CASING 13 3/8 8.540 L60 0.0 2,334.7 9/24/2010 Last Leakoff Test Depth(ftKB) 'TVD(ftKB) Fluid Type 'Fluid Density(lb/gal) I P Surf Applied(psi) Eq.Mud Weight(lb/gal) I Leak Off Pressure(psi) rti* Eni E&P Division I Well Name:0111-01 OR ENI Petroleum Co.Inc. Daily Report Well Code: 25056 Field Name:Nikatchuq o Date:9125/2010 - Report#: 7 API/ e page 1 of 1 Wellbore name: 0111-01 Well Header Permit/Concession N° I Operator I ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(It) 'Ground Level(ft) I Water Depth(n) RKB-Base Flange(ft) I RKB-Tubing Spool(ft) 53.25 12.20 0.00 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E 1LAND RIG Job Information Wellbore Job Phase I Spud Date 'Target Depth(ftKB) 'Target Depth(TVD..]Depth Dr.(MD)(ft) Drilling Hours(hr) 'Avg ROP(ft/hr) I DFS(days) 0111-01 DRILLING 9/22/2010 10,521.0 11,010.00 131.24 83.9 3.85 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(1w) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 2,347.0 2,169.5 0.00 90.0 25.7 Partly Cloudy.WC 192°SSW @ 10.8 15.4° mph Daily summary operation 24h Summary RAN 13-3/8"CASING TO 2,334'. MAKE UP TORQUE.AVERAGE ON TEN JOINT(5,500). 25 CENTRALIZERS SPACED OUT AS PER WELL PLAN. CIRCULATED AND CONDITIONED HOLE FOR CEMENT JOB. CEMENTED 13.3/8"CASING. N/D RISER. R/D CASING TOOLS. L/D LANDING JOINT AND NIPPLE DOWN RISER. NIPPLE UP BOPE AND WELLHEAD. INSTALL VALVES AND TEST.SET BOP STACK AND N/U CHOKE LINE. Operation at 07.00 COMPLETING N/U BOPE. PREPARING TO TEST BOPE. 24h Forecast NIPPLE UP AND TEST BOPE. P/U BHA#3. DRILL AHEAD WITH 12-1/4"HOLE TOWARD INTERMEDIATE HOLE TD. Lithology I Shows MAASP Pressure(psi) I Mud Weight(lb/gal) 9.40 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 03:00 3.00 3.00 DRILL G 4 P CONTINUE TO RIH FROM 590'TO 2,334'WITH 13-3/8"L80 BUTTRESS MODIFIED CASING.M/U TO=5,500. INSTALLED 25-13-3/8 BOW SPRING CENTRALIZERS. TOP OFF EVERY 10 JTS. HAD PROPER FILL. M/U LANDING JT. NO TIGHT SPOTS. UP WT=195 DN WT=145. 03:00 05:30 2.50 5.50 DRILL G 7 P CIRCULATE AND CONDITION HOLE. CBU 3X AT 8 BPM WITH 430 PSI UNTIL MUD WAS IN GOOD CONDITION AS • • PER M-I MUD ENGINEER. 05:30 06:30 1.00 6.50 DRILL G 5 P RIG DOWN GBR FRANK'S TOOL. RIG UP CEMENT HEAS AND LINES. • • 06:30 08:00 1.50 8.00 DRILL H 1 P CIRCULATE AND CONDITION. CIRCULATE AT 6 BPM WITH 250 PSI. RECIPROCATE CASING.UP WT=195 DOWN WT=145. PERFORM PJSM WITH ALL HANDS INVOLVED IN CEMENT JUB. 13A LH UP LtMLNT PER SLB CEMENTER. ."S' 08:00 12:00 4.00 12.00 DRILL H 7 P BATCH UP MUD PUSH(100 BBLS). PUMPED 5 BBLS OF WATER.PRESSURE TEST LINES TO 3,000 PSI. PUMPED 100 BBL MUD PUSH. DROPPED THE BOTTOM PLUG. PUMPED 533 BBLS.OF LEAD CEMENT 10.7 PPG. YIELD CIA 2.33 CU.FT/SACK 533 BBLS.10.367 GAL/SACK FOLLOWED BY 70 BBLS LITECRETE 12.5 PPG. YIELD 1.54,5.174 GAL/SK. DROP TOP PLUG.PUMPED 10 BBLS OF WATER. TURNED OVER TO RIG PUMPS. DISP,ACE WITH 329 BBLS OF 9.2 PPG SPUD MUD AT 7 BPM. SLOW TO 3 BBLS FOR 15 BBLS. BUMPED PLUG ON STROKES(3,249). HELD 500 OVER FCP. 1,100 PSI. BLED OFF FLOATS HELD. CIP AT 1200 HOURS(2,02.Elap OF CEMENT TO SURFACE). ' 12:00 18:00 6.00 18.00 DRILL H 5 P WASH OUT RISER RETARD. ALL FLUID IN VAC TRUCKS. N/D RISER. R/D CASING TOOLS. L/D LANDING JOINT AND NIPPLE DOWN RISER. CALCULATED TOP OF TAIL CEMENT AT 1,269'. 18:00 00:00 6.00 24.00 DRILL E 5 P NIPPLE UP BOPE. NIPPLE UP WELLHEAD. INSTALL VALVES. TEST TO 5,000 PSI. SET BOP STACK. NIPPLE UP I CHOKE LINE. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener Eni Petroleum Sr.Ddg.Spvr. Jack.Keener@enipetroleum.com 907-670-8623 907-715-6434 Eni representative Gary Goedich Eni Petroleum Ddg.Spvr. 907-670-8623 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-670-8607 907-575-9427 Eni representative Jack Potter Eni Petroleum HSE 907.685-1227 907-632-2236 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-8539 Last Casing seat Cas.Type OD(in) ID(in) `.Grade Top(5KB) Bottom(11KB) Run Date CASING 13 3/8 8.540 L80 0.0 2,334.7 9/24/2010 Last Leakoff Test Depth(f1KB) 'TVD(ftKB) 'Fluid Type 'Fluid Density(lb/gal) IP Surf Applied(psi) 'Eq.Mud Weight(lb/gal) [Leak Off Pressure(psi) 2,334.7 2,160.27 LSND 8.85 360.0 12.061 1,353.2 • friii* Eni E&P Division /Well Name:0111-01 OR EN!Petroleum Co.Inc. Daily Report` Well Code:25056 Field Name:Nikatchuq eno• Date:9/26/2010 - Report#: 8 APUWN: page 1 of 1 Wellbore name: 0111-01 •Well Header 402100 errmit/Concession N° IENI PETROLEUM IENI Share(%) 100.001 HORIZON ALation type Rotary Table Elevation(ft) Ground Level(ft) 'Water Depth(ft) I RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.25 12.20 0.00 Rig Information • Contractor I Rig Name /Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore /Job Phase Spud Date !Target Depth(ftKB) 'Target Depth(TVD..1 Depth Dr.(MD)(ft) Drilling Hours(hr) 'Avg ROP(ft/hr) 1 DFS(days) 0111-01 DRILLING 9/22/2010 10,521.0 11,010.00 131.24 83.9 4.85 Daily Information End Depth(RKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) 'Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 2,347.0 2,169.5 0.00 88.0 24.1 Partly Cloudy WC 186°S gD 11.6 mph 13.1° Daily summary operation 24h Summary NIPPLED UP AND TESTED BOPE. P/U BHA#3. SHALLOW TESTED MWD TOOLS. RIH WASHED DOWN AND TAGGED AT 2,241'. PRESSURE TESTED CASING TO 2,500 PSI. DRILLED FIRM CEMENTTO 2,329'. TAGGED SHOE AT 2,331'. DROPPED THRU AT 2,331'. Operation at 07.00 PREPARING TO DRILL AHEAD WITH 12-1/4"HOLE. 24h Forecast DRILL AHEAD WITH 12-1/4"HOLE TOWARDS INTERMEDIATE TD AT 6,315'. Lithology 'Shows MAASP Pressure(psi) I Mud Weight(lb/gal) 8.90 Time Log Start End Cum / Time Time Dur(hr) Dur(h(hr) Phase Opr. Act. Plan Oper.Deser. s// 00:00 04:00 4.00 4.00 DRILL C 5 P NIPPLE UP BOPE. NIPPLE UP KILL LINES,FLOWLINE,RKB,PITCHER NIPPLE,KATCH KAN/CURTAIN ASSEMBLY. 04:00 06:30 2.50 6.50 DRILL C 5 P P/U TEST TOOLS. M/U TEST EQUIPMENT/TEST JOINT. INSTALL TEST PLUG,FLUID PACK CHOKE MAINFOLD AND STACK. BODY TEST TO 2,500 PSI. REPLACE LEAKING DART VALVE. 06:30 12:00 5.50 12.00 DRILL C 12 P TEST BOPE TO 250 PSI LOW/3,500 PSI HIGH. HOLD TEST FOR 5 MINUTES. CHARTED. DRAW DOWN TEST. TESTS WITNESSED BY JONES AOGCC. 12:00 13:30 1.50 13.50 DRILL C 12 P PULL WEAR TEST PLUG.SET WEAA R BUSHING.TEST GAS ALARMS,SUPER CHOKE,MANIFOLD CHOKE.CHECK PVT'S. CHECK FLOW SHOW AS PER AOGCC REPRESENTATIVE. 13:30 17:30 4.00 17.50 DRILL E 4 P MU BHA#3 AS PER SLB DD. RIH WITH COLLARS,JARS AND HWDP. 17:30 18:00 0.50 18.00 DRILL 'E 4 P 'RIH TO 1,038'. MU GHOST REAMER. 18:00 18:30 0.50 18.50 DRILL E 12 P SHALLOW TEST MWD TOOLS.700 GPM 950 PSI AND 800 GPM 1,200 PSI. 18:30 19:30 1.00 19.50 DRILL E 4 P WASH DOWN STAND#17.TAG PLUG AT 2,241'. 40 RPM 110 STROKES 475 GPM 520 PSI 19:30 20:30 1.00 20.50 DRILL E 3 P CIRCULATE AND CONDITION HOLE. STAND BACK 1 STAND. PUT IN HEAD PIN. CIRCULATE 2,800 STROKES BOTTOMS UP. 140 STROKES 1,570 PSI 600 GPM 20:30 21:30 1.00 21.50 DRILL E 12 P PRESSURE TEST CASING SHOE TO 2,500 PSI. CHARTED. 33 STROKES TO PRESSURE. 3.3 BBLS PUMPED. 3.3 BBLS BLEED OFF. 21:30 22:30 1.00 22.50 DRILL E 3 P DRILLING CEMENT. TAG FLOAT AT 2,241'. WOB 12K, 40-60 RPM 700 GPM,170 STROKES,1,170 PSI,TO ON 4,800,TO OFF 3,500, UP WT=125K,DN WT=95K,ROT WT=110K. MUD WT=9.3.DROPPED THRU AT 2.248'. 22.30 23:30 1.00' 23.50 DRILL E 3 P DRILLED FIRM CEMENT TO 2,329'.TAGGED SHOE AT 2,331'. WOB=12K,RPM=40-60 GPM=700, STROKES=170,PSI=1,170,TO ON=4,800,TO OFF=3,500, UP WT=125K DN WT=95K, ROT=110K. MUD WT =9.3. 23:30 00.00 0.50 24,00 DRILL E 3 P TAG SHOE AT 2,331'. DROPPED THRU AT 2,331'. DRILLING PARAMETERS ARE SAME AS ABOVE. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener Eni Petroleum Sr.Drig.Spur. Jack.Keenert enipetroleum,com 907-670-8623 '907-715-6434 Eni representative Gary Goerlich Eni Petroleum Drig.Spur. 907-670-8623 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-670-8607 907-575-9427 Eni representative Jack Potter Eni Petroleum HSE 907-685-1227 907.632-2236 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher _907-670-8539 Last Casing seat Cas.Type OD(in) ID ID(in) Grade Top(RKB) Bottom(ftKB) Run Date CASING 13 3/8 8.540 L80 0.0 2,334.7 9/24/2010 Last Leakoff Test Depth(ftKB) 'TVD(ftKB) (Fluid Type 'Fluid Density(lb/gal) IP Surf Applied(psl) Eq.Mud Weight(lb/gal) !Leak Off Pressure(psi) 2,334.7 2,160.27 LSND 8.85 360.0 12.06 1,353.2 Irijillt‘l En!E&P Division I Well Name:0111-01 OR ENI Petroleum Co.Inc. Daily Report Well Code:25056 Field Name:Nikatchuq (�n• Date:9/27/2010 - Report#: 9 APVUWI: t i "� page 1 of 1 Wellbore name: 0111-01 Well Header 402100 Concession N' I ENI PETROLEUM I ENI Share(%) 100.00'OR Z NTAL Configuration type Rotary Table Elevation(ft) 'Ground Level(ft) 'Water Depth(ft) RKB-Base Flange(ft) I RKB-Tubing Spool(ft) 53.25 12.20 0.00 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore 'Job Phase Spud Date 'Target Depth(ftKB) 'Target Depth(TVD...I Depth Dr.(MD)(ft) 'Drilling Hours(hr) Avg ROP(ft/hr) I DFS(days) 0111-01 DRILLING 9/22/2010 10,521.0 11,010.00 131.24 83.9 5.85 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) -Avg ROP(ft/hr) POB Temperature('F) Weather Wind 3,719.0 2,858.0 1,372.00 13.98 98.1 84.0 20.5 Partly Cloudy WC 134°SE(rl 7.8 mph 10.9° Daily summary operation 24h Summary DRILLED 20'FEET OF NEW HOLE FROM 2,347'TO 2,367'. DISPLACED WELL FROM SPUD MUD TO LSND WATER BASED MUD SYSTEM. PERFORMED LOT.LOT WAS 12.1 EMW. ROTARY DRILLED FROM 2,367'TO 3,719'. Operation at 07.00 • DRILLING AHEAD AT 4,040'WITH 12.1/4"HOLE. 24h Forecast DRILL AHEAD WITH 12-1/4"HOLE TO INTERMEDIATE CASING POINT. Lithology 'Shows MAASP Pressure(psi) I Mud Weight(lb/gal) 8.90 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 00:30 0.50 0.50 DRILL E 3 P DRILL 20'OF NEW HOLE FROM 2,347'TO 2,367'. SPM=180 PSI=1,150 GPM=755 RPM=60 TO=3500 00:30 02:00 1.50 2.00 DRILL E 11 P CIRCULATE BOTTOMS UP.DISPLACE HOLE TO LSND MUD.. 8.8 MUD WEIGHT AS PER M-1 MUD ENGINEER. SPM=180 GPM=750 PSI=900 02:00 03:00 1.00 3.00 DRILL E 11 P R/U TESTING EQUIPMENT. PEREORMIOT TEST EMW=12 1 CHARTED TEST. 03:00 03:30 0.50 3.50 DRILL E 11 P RIG DOWN AND BLOW DOWN TESTING RQUIPMENT. 03:30 12:00 8.50 12.00 DRILL E 3 P DRILLED AHEAD FROM 2,367'TO 2,953'. GPM=900 SPM=215 PSI=1.290 OFF PSI=1,320 ON TQ OFF=3,600 TO ON=5,500 WOB=2-20 RPM= 140 UP WT=120K DN WT=100K ROT WT=110K MUD WT=8.9 ECD=9.42 SPR AT 2,560'#1 PUMP 35/92;45/120 #2 PUMP 35/92 45/116. ADT=5.56 JARS=36.10 12:00 18:00 6.00 18.00 DRILL E 3 P ROTARY DRILLING FROM 2,953'TO 3,230'. WOB=5-20K SPM=215 GPM=900 PSI ON=1,340 PSI OFF=1,350. TO ON=8,900 TO OFF=4,700 UP WT=120K ON WT=92K ROT WT=110K RPM=65-130 MUD WT=8.8 ECD 9,16 18:00 00:00 6.00 24.00 DRILL E 3 P ROTARY DRILLING FROM 3,230'TO 3,719'(2,820'ND. WOB=2/15 SPM=215 GPM=900 PSI ON=1.450 PSI OFF=1,460 TO ON=5,500 TQ OFF=3,600 UP WT=120K DN WT=100K ROT WT=110K RPM=140 MUD WT=8.9 ECD=9.42 SPR AT 3,230'(2,646' TVD)#1 35/140;45/160.#3 35/145; 45/170.ADT=8.42 JARS=36.10 Daily Contacts Position Contact Name Company Tide E-mail Office Mobile Eni representative Jack Keener 'Eni Petroleum Sr.Drig.Spvr. Jack.Keener@enipetroleum.com '907-670-8623 907-715-6434 Eni representative Gary Goerlich Eni Petroleum Dig.Spvr. 907-670-8623 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-670-8607 907-575-9427 Eni representative Jack Potter Eni Petroleum HSE 907-685-1227 907-632-2236 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-8539 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(RKB) Run Date CASING 13 3/8 8.540 L80 0.0 2,334.7 9/24/2010 Last Leakoff Test Depth(ftKB) ITVD(ftKB) Fluid Type 'Fluid Density(lb/gal) IP Surf Applied(psi) Eq.Mud Weight(Iblgal) Leak Off Pressure(psi) 2,334.7 2,160.27 LSND 8.85 360.0 12.06 1,353.2 1r541k1/4 Eni E&P Division Ewen Name:on 1-01 OR ENI Petroleum Co.Inc. Daily Report Well Code:25056 Field Name:Nikatchuq Date:9/28/2010 - Report#: 10 API/uwh �� page 1 of 1 Wellbore name: 0111-01 Well Header Permit/Concession N• 'Operator I ENI Share(%) 100.00!WOR C N7ALation type 402100 EN1 PETROLEUM Rotary Table Elevation(ft) Ground Level(ft) 'Water Depth(ft) RKB-Base Flange(ft) I RKB-Tubing Spool(ft) 53.25 12.20 0.00 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E 'LAND RIG Job Information Wellbore 'Job Phase Spud Date 'Target Depth(ftKB) !Target Depth(TVD...I Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) IDFS(days) 0111-01 DRILLING 9/22/2010 10,521.0 11,010.00 131.24 83.9 6.85 Daily Information End Depth(ftKB) End Depth(ND)(f..'Depth Progress(ft) 'Drilling Hours(hr) (Avg ROP(ft/hr) 1POB Temperature(•F) 'Weather 'Wind 4,711.0 3,216.31 992.00 13.76 72.1 87.0 27.0 Overcast.WC 15.4° 170 S @ 16.8 mph Daily summary operation • 24h Summary ROTARY DRILLED FROM 3,719'TO 4,711', ENCOUNTERED HARD SPOT AT 4,711'. POOH TO CHECK BIT AND BHA. Operation at 07.00 L/D BHA AND BIT. 24h Forecast L/D BHA. CHANGE BIT AND BHA. RIH.DRILL AHEAD TO INTERMEDIATE HOLE TD. Lithology I Shows I MAASP Pressure(psi) I Mud Weight(Iblgal) 9.00 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06:00 6.00 6.00 DRILL E 3 P DRILL AHEAD FROM 3,719'TO 4,290'. GPM=900 SPM=215 RPM=140 PSI ON=1,570 PSI OFF=1,500 TO ON=6,500 TQ OFF=5,700 WOB=4/20 UP WT=122K DN WT=97K ROT WT=110K REAMING 60'UP AND DOWN EVERY CONNECTION. ECD=9.4 PPG. SLOW PUMP RATE AT 3,818'. #1 35/165 PSI 45/195 PSI #2 35/165 PSI 45/190 PSI 06:00 12:00 6.00 12.00 DRILL E 3 P DRII I AHFAD FROM 4 290'TO 4 670' GPM=900 SPM= 215 RPM=140 PSI ON=1.700 PSI OFF=1,650 TO ON=6,700 TQ OFF=5,500 WOB=4/25 UP WT=125K DN WT=98K ROT WT=110K ECD=9.44 TVD=3186' MUD WT=8.9 PPG ADT=7.27 ENCOUNTERED HARD SPOT AT 4,610'. 12:00 18:00 6.00 18.00 DRILL E 3 P ROTARY DRILLING FROM 4,620'TO 4,665'. WOB=25K SPM=215 GPM=900 PSI ON=1,6580 PSI OFF=1,700 TO ON=12,000 TO OFF=7,000 UP WT=140K DNWT=95K ROTWT=112K RPM=65/140 MUD WT=8.9 PPG ECD=9.24 18:00 22:30 4.50 22.50 DRILL E 3 P ROTARY DRILLING FROM 4,665'TO 4,711'. (3,180'ND). WOB=5K/25K SPM=215 GPM=900 PSI ON=1,670 PSI OFF=1,680 TO ON=12,000 TQ OFF=7,500 TQ ON=12,500 UP WT=140K DN WT=95K ROT WT=112K RPM=65 MUD WT=8.9 PPG ECD=9.24 SLOW PUMP RATE: #1 35/150 45/180 #2 35/160 45/185 AT 4,711' (3,180 ND). ADT=6.49 JARS=50.14 22:30 00:00 1.50 24.00 DRILL E 4 P POOH TO 3,380', UP WT=150K DN WT=90K. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Jack Keener Eni Petroleum Sr.Ddg.Spvr. Jack.Keener@enipetroteum.com 907-670-8623 907-715-6434 Eni representative Gary Goedich Eni Petroleum 04g.Spvr, 907-670-8623 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-670-8607 907-575-9427 Eni representative Jack Potter Eni Petroleum HSE 907-685-1227 907-632-2236 • Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 • • Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-8539 Last Casing seat Cas.Type ' OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 13 3/8 8.540 L80 0.0 2,334.7 9/24/2010 Last Leakoff Test Depth(ftKB) 1TVD(ftKB) Fluid Type 'Fluid Density(Iblgal) I P Surf Applied(psi) I Eq. Mud Weight(lb/gal) 1 Leak Ott Pressure(psi) 2,334.7 2,160.27 LSND 8.85 360.0 12.06 1,353.2 Eni E&P Division Well Name:0/11-01 OR EN?Petroleum Co.Inc. Daily Report Well Code:25056 Field Name:Nikatchuq • APIIIW I: e(� Vif*��,�,,I Date:9/29/2010 • Report#: 11 page 1 of 1 Wellbore name: 0111-01 Well Header 402100 Concession N° IENI PETROLEUM IENI Share(i) 100.001 HORIZONTALConfiguration type Rotary Table Elevation(ft) 'Ground Level(ft) !Water Depth(ft) I RKB-Base Flange(ft) I RKB-Tubing Spool(ft) 53.25 12.20 0.00 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245E LAND RIG Job Information Wellbore Job Phase (Spud Date 'Target Depth(ftKB) Target Depth(TVD...I Depth Dr.(MD)(ft) 'Drilling Hours(hr) Avg ROP(ft/hr) I DFS(days) 0111-01 DRILLING 9/22/2010 10,521.0 11,010.00 131.24 83.9 7.85 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(Whr) POB Temperature(°F) Weather Wind 4,711.0 3,216.3 0.00 86.0 27.1 Partly Cloudy.WC 200°SSW @ 7.8 19° mph Daily summary operation 24h Summary TRIP OUT OF HOLE TO CHECK BIT AND TOOLS. PDC BIT WAS GRADED 6-7-BT-A-X-1/16-CT-PR. IT WAS DECIDED TO RUN A MOTOR AND MILLTOOTH BIT TO COMPLETE THE INTERMEDIATE HOLE SECTION. LAYED DOWN XCEED AND MWD/LWD TOOLS. PICKED UP BHA#4. SHALLOWED TEST MWD. CUT AND SLIPPED THE DRILLING LINE 72 FT. SERVICED TOP DRIVE BLOCKS AND CROWN. TRIPPED IN HOLE TO 4,580'. WASHED AND REAMED FROM 4,580'TO 4,708'. Operation at 07.00 DRILLING AHEAD WITH 12-1/4"HOLE AT 4,857'. 24h Forecast DRILL AHEAD WITH MOTOR AND MILLTOOTH BIT TO INTERMEDIATE HOLE SECTION TOTAL DEPTH. Lithology 'Shows MAASP Pressure(psi) I Mud Weight(lb/gal) 9,05 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. • 00:00 02:30 2.50 2.50 DRILL E 4 P POOH FROM 3,410'TO 650'. ENCOUNTERED TIGHT SPOT AT 2,871'. WORKED THROUGH TIGHT SPOT. 30K OVERPULL. PROPER HOLE FILL. NO SWAB. 02:30 04:30 2.00 4.50 DRILL E 4 P LAY DOWN BHA. RACK BACK HWDP,JARS,AND DRILL COLLARS. CHECK AND BREAK OUT STABILIZER AND 12- 1/4"PDC BIT. BIT 1/8"UNDERGAUGE. 04:30 07:30 3.00 7.50 DRILL E 4 P UPLOADING LWD AND EXCEED TOOLS PER SLB. CLEAN DRILL FLOOR. 07:30 09:30 2.00 9.50 DRILL E 4 P LAY DOWN LWD,MWD,STABILIZER AND EXCEED TOOLS AS PER SLB. 09:30 12:00 2.50- 12.00 DRILL E 4 P PICK UP BHA#4 AS PER SLB DIRECTIONAL DRILLER. RAN 12-1/4"TRICONE BIT,STABILIZER AND MOTOR. 12:00 13:30 1.50 13.50 DRILL E 4 P MAKE UP BHA AS PER SLB DD. RIH WITH COLLARS,JARS AND HWDP. 13:30 14:00 0.50 14.00 DRILL 'E 4 P RIH TO 1,100'. 14:00 14:30 0.50 14.50 DRILL E 4 P SHALLOW TEST MWD AND LWD TOOLS. SPM=170 GPM=700 PSI=1,800 14:30 15:30 1.00- 15.50 DRILL E 4 P RIH TO 2,243'. 15:30 17:00 1.50 17.00 DRILL E 4 P CUT DRILLING LINE 72 FT. SERVICE TOP DRIVE,BLOCKS AND CROWN. 17:00 19:30 2.50 19.50 DRILL E 4 P TRIP IN HOLE FROM 2,243'10 4,580'. UP WT=150K ON WT=100K. TIGHT HOLE FROM 3,390'TO 3,990'. 19:30 00:00 4.50 24.00 DRILL E 4 P REAMING AND WASHING FROM 4,580'TO 4,708'. WOB 30K SPM=200 GPM=850 PSI ON=2,900 PSI OFF=2,800 TO ON=8,700 TO OFF=6,000 UP WT=150K DN WT=100K ROT WT=120K ECD=9.24 MUD WT=9.0 PPG HOLE UNDER GAUGE FROM 4,690'TO 4,708'. Daily Contacts Position Contact Name _ Company Title E-mail Office Mobile Eni representative Jack Keener Eni Petroleum Sr.Dig.Spvr. Jack.Keener(@enipetroleum.com -907-670-8623 907-715-6434 Eni representative Gary Goerlich Eni Petroleum Drlg.Spvr. 907-670-8623 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-670-8607 907-575-9427 Eni representative Jack Potter Eni Petroleum HSE 907-685-1227 907-632-2236 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Mark Ashley Nabors Alaska Drilling Tool Pusher 907-670-8539 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(RKB) Run Date CASING 13 3/8 8.540 L80 0.0 2,334.7 9/24/2010 Last Leakoff Test Depth(ftKB) I TVD(ftKB) Fluid Type 'Fluid Density(lb/gal) IP Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 2,334.71 2,160.27 LSND 8.85 360.0 12.06 1,353.2 En!E&P Division �Weoivame('on,-0,OR EN!Petroleum Co.Inc. Daily Report Well Code:25056 Field Name:Nikatchuq n Date:9/30/2010 - Report#: 12 °P1/w^' n II page 1 of 1 Wellbore name: 0111-01 Well Header Permit/Concession N° 'Operator I ENI Share(%) 'Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) I Ground Level(ft) !Water Depth(ft) RKB-Base Flange(ft) I RKB-Tubing Spool(ft) 53.25 12.20 0,00 Rig Information Contractor Rig Name I Rig Type NABORS ALASKA NABORS 245E LAND RIG Job Information Wellbore Job Phase I Spud Date !Target Depth(ftKB) (Target Depth(TVD..]Depth Dr.(MD)(ft) I Drilling Hours(hr) !Avg ROP(ftlhr) I DFS(days) 0111.01 DRILLING 9/22/2010 10,521.01 11,010.00 131,24 83.9 8.85 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) !Drilling Hours(hr) !Avg ROP(ft/hr) IPOB Temperature(°F) I Weather I Wind 5,016.0 3,325.1 305.00 6.49 47.0 84.0 27.3 Cloudy.WC 24.8° 324°NW @ 2.5 mph Daily summary operation 24h Summary WASHED AND REAMED FROM 4,708'TO 4,711'. ROTARY DRILLED FROM 4,711'TO 5,016', ENCOUNTERED PRESSURE LOSS,3,600 PSI TO 2,300 PSI. SURFACED TESTED EQUIPMENT. TESTED OK. POSSIBLE DOWN HOLE PROBLEMS. POOH ON ELEVATORS FROM 5,016'TO 650'. LAYED DOWN GHOST REAMER,HWDP,AND BHA#4. CLEANED FLOOR AND SERVICED TOP DRIVE. PICKED UP BHA#5. RIH AND SHALLOW TESTED TOOLS. Operation at 07.00 TRIPPING IN HOLE AT 4,405'. 24h Forecast RIH WITH BHA#5. DRILL AHEAD TO INTERMEDIATE HOLE TD. Lithology 'Shows MAASP Pressure(psi) I Mud Weight(lb/gal) • 8.95 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Dosser. 00:00 01:00 1.00 1.00 DRILL 'E 3 P CONTINUED TO WASH AND REAM TO BOTTOM FROM 4,708 TO 4.711', RPM=50 PSI=3,000 GPM=900 TO 7,200. 01:00 06:00 5.00 6.00 DRILL E 3 P ROTARY DRILLED FROM 4,711'TO 4,940'. GPM=900 SPM=215 PSI ON=3.600 PSI OFF=3,500 TQ ON=8,500 TO OFF=7,500 RPM 60/90 WOB =4/28 UP WT=150K DN WT=100K ROT WT=120K MW=9.0 PPG ECD=9.50 06:00 10:00 4,00 10.00 DRILL E 3 P ROTARY DRILLED FROM 4,940'TO 5,019'. GPM=900 SPM=215 PSI ON=3,250/3,600 PSI OGG=3,500 TO ON=7K/8K TO OFF=6K RPM=60/90 WOB=4/28 UP WT-150K ON WT=WOK ROT WT=120K TVD=3,328' ECD=9.4 ADT=6.49 10:00 11:00 1.00 11.00 DRILL E 11 U TEST STANDPIPE MANIFOLD. ENCOUNTERED PRESSURE LOSS OF 3,600/2,300 PSI. TEST SURFACE EQUIPMENT TO 1,200 PSI. TEST OK. DOWN HOLE/TOOL PROBLEMS. 11:00 12:00 1.00 12.00 DRILL E 4 P POOH ON ELEVATORS FROM 5,019'TO 4,184'. NO SWAB/DRAG. PROPER HOLE FILL. 12:00 15:00 3.00 15.00 DRILL E 4 P POOH FROM 4,184'TO 650'. NO DRAG. LAY DOWN GHOST REAMER. 15:00 16:00 1.00 16.00 DRILL E 4 P STAND BACK HWDP/JARS/COLLARS. 16:00 18:00 2.00 18.00 DRILL E 4 P POOH AND INSPECT BHA. LAY DOWN BIT,CENTRALIZERS,POWER PULSE, ARC AND MUD MOTOR. 18:00 21:00 3.00 21.00 DRILL E 4 P CLEAN FLOOR. SERVICE TOP DRIVE. 21:00 23:00 2.00 23.00 DRILL E 4 P M/U BHA#5 AS PER SLB DIRECTIONAL DRILLER. RIH WITH COLLARS,JARS,2 JOINTS HWDP. 23:00 00:00 1.00 24.00 DRILL E 4 P RIH WITH 7 STANDS DRILL PIPE,GHOST REAMER,1 STAND DRILL PIPE. SHALLOW TEST TOOLS. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener Eni Petroleum Sr.Drlg.Spvr. Jack.Keenerrtenipetrcleum.com 907.670.8623 907-715-6434 Eni representative Gary Goerlich Eni Petroleum Dog.Spvr. 907-670-8623 Eni representative Bemie Leas Eni Petroleum Rig Clerk 907-670-8607 907-575-9427 Eni representative Jack Potter Eni Petroleum HSE 907-685-1227 907-632-2236 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Mark Ashley Nabors Alaska Drilling Tool Pusher 907-670-8539 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 13 3/8 8.540 L80 0,0 2,334.7 9/24/2010 Last Leakoff Test Depth(ftKB) !TVD(ftKB) Fluid Type 'Fluid Density(lb/gal) IP Surf Applied(psi) IEq.Mud Weight(lb/gal) !Leak Off Pressure(psi) 2,334.7 2,160.27 LSND 8.85 360.0 12.06 1,353.2 f r"` ' Eni E&P Division Well Name:0111-01 OR EN/Petroleum Co.Inc. Daily Report` Well Code:25056 Field Name:Nikatchuq enii Date:10/1/2010 - Report#: 13 API/WN: page 1 of 1 Wellbore name: 0111-01 Well Header 402100 Concession N° I ENI PETROLEUM IENI Share(%) 100.001 HO1RIZONTAL Configuration type Rotary Table Elevation(ft) I Ground Level(ft) 'Water Depth(ft) RKB-Base Flange(ft) I RKB-Tubing Spool(ft) 53.25 12.20 0.00 Rig Information Contractor Rig Name IRig Type NABORS ALASKA NABORS 245 E I LAND RIG Job Information Wellbore I Job Phase Spud Date 'Target Depth(ftKB) 'Target r Depth(TVD...I Depth Dr.(MD)(ft) I Drilling Hours(hr) Avg ROP(ft/hr) 1 DFS(days) 0111-01 DRILLING 9/22/2010 10,521.0 11,010.00 131.24 83.9 9.85 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POD 'Temperature(°F) Weather Wind 5,936.0 3,640.9 917.00 18.50 49.6 84.0 29.8 Mostly Cloudy,WC 355°N rfp 22.7 mph 15.6° Daily summary operation 24h Summary Continue PU BHA#5 and 29 jts HWDP.TIH to 5010'MD. Rotary drill/slide to 5936'MD/3642'ND. -Total Footage-917' -ART-4.33 hrs. -AST-5.48 hrs Operation at 07.00 Currently CBU at TD 6013'MD. 24h Forecast CBU 3x or until hole dictates. BROOH to surface casing shoe and CBU+/-5x. POOH LD BHA#5. CIO and Test Rams. RU 9-5/8"casing running equipment and RIH 9-5/8"47#L80 Casing to 5992' MD Lithology 'Shows MAASP Pressure(psi) I Mud Weight(Ib/gal) 9.10 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 '01:00 1.00 1.00 DRILL E 1 P PU BHA#5-PDM 1.15 ASH and 29jts HWDP. 01:00 05:00 4.00 5.00 DRILL E 4 P TIH f/1800 V 5019'MD filling every stand. Encountered tight spots at 4405'MD,4434'MD 05:00 12:00 7.00 12.00 DRILL E 3 P Rotary Drill/Slide f/5019'MD to 5337'MD. AST-1.73 hrs,ART 1.18 hrs -900 gpm,80 rpm,6-25 WOB,175 fph -2540/2430 psi ON/OFF -8800/7500 K ft-lbs TO ON/OFF ^155 PU/98 SO/122 ROB -MW=9 ppg -ECD=9.5 EMW 12:00 12:30 0.50 12.50 DRILL E 7 P Take additional check shots to verify dog leg.5.54 DLS determined 12:30 00:00 11.50 24.00 DRILL E 3 P Drill f/5337'MD to 5936'MD.AST-3.75 hrs,ART 3.15 hrs -880 gpm,60 rpm,10-25 WOB,100 fph -2650/2515 psi ON/OFF -8000/7000 K ft-Ibs TO ON/OFF -162 PU/108 SO/128 ROB -MW=9.1 ppg -ECD=9.64 EMW Daily Contacts Position _ Contact Name Company Title E-mail Office Mobile Eni representative Joe Longo Eni Petroleum Drilling Engineer Joe.Longo @enipetroleum.com 907-865-3323 907-947-4323 Eni representative Gary Goerlich Eni Petroleum Ddg.Spvr. 907-670-8623 Eni representative Tom Norvig Eni Petroleum Rig Clerk 907-670-8607 907-229-6100 Em representative Jack Potter Eni Petroleum HSE 907-685-1227 907-632-2236 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Mark Ashley Nabors Alaska Drilling Tool Pusher 907-670-8539 Last Casing seat Cas.Type OD(in) ID(In) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 13 3/8 8.540 L80 0.0 2,334.7 9/24/2010 Last Leakoff Test Depth(ftKB) I TVD(ftKB) Fluid Type 'Fluid Density(Ib/gaq IP Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 2,334.7 2,160.27 LSND 8.85 360.0 12.06 1,353.2 I j" j Eni E&P Division 'Well Name:0111-07 OR EN!Petroleum Co.Inc. Daily Report Well Code:25056 Field Name: Nikatchuq (� Date:10/2/2010 - Report 14 APIIU8M: i " " page 1 of 1 Wellbore name: 0111-01 Well Header 402100 iConcession kr IENI PETROLEUM IENI Share(%) 100.00'Well Configuration type Rotary Table Elevation(ft) Ground Level(ft) 'Water Depth(ft) I RKB-Base Flange(ft) I RKB-Tubing Spool(ft) 53.25 12.20 0.00 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245E LAND RIG Job Information Wellbore Job Phase 'Spud Date 'Target Depth(ftKB) [Target Depth(TVD...IDepth Dr.(MD)(ft) Drilling Hours(hr) 'Avg ROP Mr) I DFS(days) 0111-01 DRILLING 9/22/2010 10,521.0 11,010.00 131.24 83.9 10.85 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ftlhr) POB Temperature(°F) Weather Wind 6,007.0 3,654.2 71.00 5.50 12.9 85.0 29.7 Mostly Cloudy,WC 5°N©16.2 mph 18° Daily summary operation 24h Summary Drill to Intermediate TO CM 6007'MD/3654.6'TVD CBIJ 3x. BROOH to Intermediate casing shoe a 2334'MD. CBU 5x. POOH on elevators and LD BHA. CO and Test 9-5/8"Casing rams-Good Test. RU GBR casing running equipment and Franks fill up tool, RIH 30 jts 9.5/8"Casing to 1250'MD. Operation at 07.00 Currently RIH 9-5/8"47#L80 BTC-M Casing at 2336'MD 24h Forecast Continue running total of 143 jts.9-5/8"47#L80 BTC-M Casing to 5990.9'MD. CBU 1-2x while reciprocating. RU SLB cementing equipment/Little Red Services and pump 204 bbls 12.5 ppg DeepCRETE. Diesel freeze protect. RD SLB and LRS and test BOPs Lithology Shows MAASP Pressure(psi) I Mud Weight(lb/gal) 8.95 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 01:00 1.00 1.00 DRILL E 3 P Rotary Drill I Slide 1/5936'MD to TD at 6007'MD/3654.6'TVD. -ADT-1.28 hrsl AST-.641 ART-.64 -900 gpm,80 rpm,10-28 WOB,100 fph -2550/2490 psi ON/OFF -8500/7500 K ft-Ibs TQ ON/OFF -162 PU/105 SO/125 ROB -MW=9 ppg -ECD=9.2 EMW 01:00 04:00 3,00 4.00 DRILL E 7 P CBU 3x while reciprocating. -900 gpm,80 rpm,7300 ft-1bs TQ -125 ROB '04:00 09:30 5.50 9.50 DRILL E 4 P BROOH fI 6013 to surface casing shoe @ 2334'MO without issue. -900 gpm 80.100 rpm 5500-8500 ft-lbs TO -123 ROB 09:30 10:30 1.00 10.50 DRILL E 7 P CBU 5x while reciprocating. -900 gpm 80 rpm 10:30 11:00 0.50 11.00 DRILL E 4 P POOH on elevators f/2334'MD-1882'MD 11:00 12:30 1.50 12.50 DRILL E 4 P Rack Back 9 Stands HWDP,10 Stands DP,and LD Ghost Reamer 12:30 15:30 3.00 15.50 DRILL E 5 P LD BHA#5 15:30 18:00 2.50 18.00 DRILL E 5 P Pull wear ring and CO top rams to 9-5/8" • 18:00 19:30 1.50 19.50 DRILL E 12 P PU Test joint and set test plug. Test 9-5/8"rams to 250/3500 5 min each-Good Test. LD Test Joint,blow down kill line P and drain stack V/,p�� 19:30 20:30 1.00 20.50 DRILL E 19 P PU VetcoGray Casing hanger and perfrom dummy run 20:30 21:30 1.00 21.50 DRILL E 5 P RU GBR casing running equipment and Franks fill up tool 21:30 00:00 2.50 24.00 DRILL E 4 P Run 30 Jts 9-5/8"47#L80 BTC-M Casing to 1251'MD. Avg MU TO 9500 ft-lbs. Filling on the fly and topping off every 10 joints. Daily Contacts Position Contact Name Company Title E-mail Office Mobile • Eni representative 'Joe Longo Eni Petroleum Drilling Engineer Joe.Longo@enipetroleum.com 907-865.3323 907-947-4323 Eni representative Gary Goerlich Eni Petroleum Drip.Spvr. 907-670-8623 • Eni representative Tom Norvig Eni Petroleum Rig Clerk 907-670-8607 907-229-6100 Eni representative Jack Potter Eni Petroleum HSE 907-685-1227 907-632-2236 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Mark Ashley Nabors Alaska Drilling Tool Pusher 907-670-8539 Last Casing seat Casa Type OD(In) ID(In) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 13 3/8 8.540 L80 0.0 2,334.7 9/24/2010 Last Leakoff Test Depth(RKB) TVD(RKB) Fluid Type 'Fluid Density(Iblgal) IP Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 2,334.7 2,160.27 LSND 8.85 360.0 12.06 1,353.2 11P*1 Eni E&P Division Ewen Name:on 1-01 OR � i EN!Petroleum Co.Inc. Daily Report Well Code:25056 Field Name:Nikatchuq e n Date:10/3/2010 - Report#: 15 APIIUWI: page 1 of 1 Wellbore name: 0111-01 Well Header Permit/Concession N° I Operator I ENI Share(i) 100.00!Well HORIZONTAL Configuration type 402100 ENI PETROLEUM Rotary Table Elevation(ft) Ground Level(ft) 'Water Depth(ft) RKB-Base Flange(ft) I RKB-Tubing Spool(ft) 53.25 12,20 0.00 t Rig Information Contractor Rig Name 1Rig Type NABORS ALASKA NABORS 245 E ILAN D RIG Job Information Wellbore /Job Phase Spud Date !Target Depth(ftKB) 'Target Depth(TVD..J Depth Dr.(MD)(ft) !Drilling Hours(hr) 'Avg ROP(ft/hr) I DFS(days) 0111-01 DRILLING 9/22/2010 10,521.0 11,010.00 131.24 83.9 11.85 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(fUhr) POB Temperature('F) Weather Wind 6,007.0 3,654.2 0.00 89.0 30.7 Mostly Cloudy,WC 5°N @ 18.3 mph 18.7° Daily summary operation 24h Summary Ran 143 Jts.9-5/8 47#L80 BTC-M Casing to 5990.9'MD/3651'ND. CBU+23(while reciprocating. RD GRB and RU SLB. Pump 211 bbls(774 sacks)12.5 ppg LiteCRETE while reciprocating. Switch to rig pumps and displace with 417 bbl 9.0 ppg LSND. Bumped plug,held 1015 psi. Bled off-Floats Held. Verify hanger landed and installed 9-5/8"packoff. Tested to 5000 psi for 10 min-Good Test. Pump 150 bbls diesel freeze protect in 13.3/8"x 9-5/8"annulus-No Issues. CO 9-5/8"casing rams to 4-1/2"x 7"VBR. Test 250/3500 psi-Good Test. Clear floor,begin cleaning pits. Load BHA and 5" DP in pipe shed. Operation at 07.00 Currently PU 5"DP. 24h Forecast PU 5"DP. MU Xceed 675 BHA#6. RIH to top of float collar. Displace to 8.7 ppg Fazepro. Drillout shoe track and 20'new hole. Conduct LOT. Lithology 'Shows 'MAASP Pressure(psi) I Mud Weight(lb/gal) 9.10 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 01:30 1.50 1.50 DRILL G 4 P Confine running 9-5/8"Casing f/1290 t/2330'MD. Filling every joint and topping off every 10. 01:30 02:00 0.50 2.00 DRILL G 7 P CBU @ 2330'MD(Surface Casing Shoe @ 2334'MD)at 7 bpm-350 psi 02:00 06:00 4.00 6.00 DRILL G 4 P Contine running 9-5/8"Casing f/2330/5327'MD. Filling every joint and topping off every 10. 06:00 07:00 1.00 7.00 DRILL G 7 P CBU @ 5327'MD at 7 bpm-400 psi -236 PU/125 SO 07:00 08:00 1.00 8.00 DRILL G 4 P Confine running 9-5/8"Casing f/5327'to casing point(t)5990.9'MD/3651'ND. Filling every joint and topping off every 10. PU VetcoGray landing joing and land mandrel hanger. 08:00 09:00 1.00 9.00'DRILL G 5 P RD GBR casing running equipment and Franks fillup tool. RU SLB CMT head and lines. 09:00 10:30 1.50 10.50 DRILL G 7 P CBU+2x at 7 bpm-380 psi while reciprocating. -258 PU/130 SO f 1030 12:00 1.50 12.00 DRILL H 9 P PJSM w/SLB. Pump 5 bbls H2O and Test Lines to 4000 psi-Good Test. Pump 12.5 ppg LiteCRETE cement job while recirprocafing. ROMPING SCHEDULE Cl;(ump 5 bbls H2O,Test Lines to 4000 psi-Good Test t/, -Pump 71.5 bbls 10.5 ppg Mud Push -Drop btm plug and pump 211 bbls(774 sacks)12.5 ppg LiteCrete(Yield 1.53) • -Drop top plug,pump 10 bbls H2O -Displace 417 bbls 9.0 ppg LSND with rig pumps(4170 stk,calculated 4220 stk) -Hold 1015 psi(500 psi over circulating pressure),bleed off and check float-Holding d 12:00 13:30 1.50 13,50 DRILL H 9 P Switch to rig pumps and displace with 9.0 ppg LSND. Displaced at 8 bpm while reciprocating.At 3900 stks(390 bbls) slowed pumps to 2.8 bpm. Landed hanger at 4031 stks(403.1 bbls). Bumped plug at 4170 stks(417 bbls)approximaty 50 stks early. Held 1015 psi(500 over circulating pressure). Bled off and checked floats-Floats held, • 13:30 14:30 1.00 14.50 DRILL H 5 P RD SLB cement head and blow down lines. Pump out stack and verify hanger landed. Remove casing elevators and cement head from rig floor, 14:30 15:30 1.00 15.50 DRILL G 5 P Set 9-5/8"packoff and test to 5000 psi for 10 min-Good Test. LD running tool. 15:30 17:30 2.00 17.50 DRILL G 9 P CO upper rams to 4-10"x 7"VBR's. Freeze protect 13-3/8"x 9-5/8"annulus with 150 bbls diesel,500-700 psi circulating pressure-No issues. 17:30 18:30 1.00 18.50 DRILL E 12 P Test and record 4-1/2"x 7"VBR's to 250/3500 psi for 5 min each-Good Test. LD test plug and set wear ring. 18:30 00:00 5.50 24.00 DRILL E 1 P Begin cleaning pits.Load SLB logging tools and 5"DP in shed, CO bladder on koomey bottle. Clean rig floor,cellar, shaker area. CO shaker screens. Daily Contacts Position Contact Name Company Title E-mail Office Mobile , Eni representative Joe Longo Eni Petroleum Drilling Engineer Joe.Longo@enipetroleum.com 907-865-3323 907-947-4323 Eni representative Gary Goerlich Eni Petroleum Drtg.Spvr. 907-670-8623 Eni representative Tom Norvig Eni Petroleum Rig Clerk 907-670-8607 907-229-6100 Eni representative Jack Potter Eni Petroleum HSE 907-685-1227 907-632-2236 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Mark Ashley •Nabors Alaska Drilling Tool Pusher 907-670-8539 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 9 5/8 'L80 -6,487.9 5,990.9 10/3/2010 Last Leakoff Test Depth(ftKB) TVD(ftKB) I Fluid Type 'Fluid Density(Iblgal) IP Surf Applied(psi) Eq.Mud Weight(Iblgal) Leak Off Pressure(psi) 2,334.7 2,160.27 LSND 8.85 360.0 12.06 1,353.2 Eni E&P Division �Well Name:0111-01 OR ENI Petroleum Co.Inc. Daily Report Well Code:25056 Field Name:Nikatchuq V1 II*•n APIIUWI: e n o Date:10/4/2010 - Report#: 16 page 1 of 1 Wellbore name: 0111-01 Well Header 402100 Concession N° I ENI PETROLEUM IENI Share(%) 100.001 HORIZ NTALation type Rotary Table Elevation(ft) 'Ground Level(ft) 1 Water Depth(ft) RKB-Base Flange(ft) I RKB-Tubing Spool(ft) 53.25 12.20 0.00 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E 'LAND RIG Job Information Wellbore 1 Job Phase Spud Date !Target Depth(ftKB) 'Target Depth(TVD..I Depth Dr.(MD)(ft) [Drilling Hours(hr) Avg ROP(ft/hr) 1 DFS(days) 0111-01 DRILLING 9/22/2010 10,521.0 11,010.00 131.24 83.9 12.85 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 6,007.0 3,654.2 0.00 84.0 30.9 Mostly Cloudy,WC 5°N @ 13 mph 20.7° Daily summary operation 24h Summary PU and rack back 108 its(36 stands)5" DP. Loaded 150 jts 4-1/2"12.6#L80 IBT-M tubing in pipe shed. PU 8.1/2"Xceed 675 BHA#6 and TIN to 2300'MD. Slow running speed to 900 fph for sonic log memory data to top of float collar @ 5904'MD for future CBL comparison. Test 9-5/8"casing to 3000 psi for 30 min-Good Test. Displace 9.0 ppg LSND to 8.6 ppg FazePro OBM. Operation at 07.00 Currently cleaning pits and preparing to drill out float equipment and shoe track. Strapping 4-1/2"12.6#L80 IBT-M tubing in pipe shed. 24h Forecast Continue to condition 8.6 ppg FazePro OBM and clean pits. Drillout shoe track and 20'new hole to 6027'MD. Pull into 9-5/8"casing shoe and perform LOT. Drill ahead 8-1/2"OH. Lithology Shows MAASP Pressure(psi) Mud Weight(Iblgal) 8.70 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act, Plan Oper Deser. 00:00 06:30 6.50 6.50 DRILL E 1 P PU total 108 jts.(36 Stands)5"DP from shed. 06:30 08:30 ' 2.00 8.50 DRILL E 4 P POOH and rack back 36 stands DP and breakout mule shoe. 08:30 09:30 1.00 9.50 DRILL E 1 P Grease drawworks,iron ruffneck,topdrive and clean drill floor. 09:30 10:00 0.50' 10.00 DRILL E 1 P PJSM on picking up BHA#6 10:00 13:30 3.50 13.50 DRILL E 5 P PU 8.1/2"Xceed 675 BHA#6 and shallow test tools-OK 13:30 14:00 0.50 14.00 DRILL E 4 P TIH to 2300'MD. 14:00 20:00 6.00 20.00 DRILL E 4 P TIH fl 2300'MD to top of float collar @ 5904'MD while maintaing 900 fph to capture sonic bond log memory data for future CBL comparison. 20:00 20:30 0.50 20,50 DRILL E 7 P CBU 485 gpm,1200 psi. 20:30 22:30 2.00 22.50 DRILL E 12 P Pressure test 9-5/8"casing to 3000 psi for 30 min and record on chart-Good Test. RD and blowdown lines. 22:30 00:00 1.50 24.00 DRILL E 7 P Pump 35 bbl spacer and displace 9.0 ppg LSND to 8.6 ppg FazePro OBM. Clean possum belly,shakers,underflow and trough. Strapping 150 jts.4-1/2"12.68 L80 IBT-M tubing in pipe shed. Daily Contacts Position Contact Name Company Tide E-mail Office Mobile Eni representative Joe Longo Eni Petroleum Drilling Engineer Joe•Longo @enipetroleum.com 907-865-3323 907-947-4323 Eni representative Gary Goerlich Eni Petroleum Drig.Spvr. 907-670-8623 Eni representative Tom Norvig Eni Petroleum Rig Clerk 907-670-8607 907-229-6100 Eni representative Jack Potter Eni Petroleum HSE 907-685-1227 907-632-2236 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Mark Ashley Nabors Alaska Drilling Tool Pusher 907-670-8539 Last Casing seat Ces.Type L OD(in) ID(in) Grade -- Top(ftKB) Bottom'(ftKB) Run Date CASING 95/8' L80 -6,487.9 5,990.9 10/3/2010 Last Leakoff Test Depth(ftKB) 1TVD(ftKB) Fluid Type I Fluid Density(Iblgal) IP Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 2,334.7 2,160.27 LSND 8.85 360.0 12.06 1,353.2 • "' ' Eni E&P Division 'Well Name:0111-01 OR ENI Petroleum Co.Inc. Daily Report Well Code:25056 Field Name:Nikatchuq e i Date:10/5/2010 - Report#: 17 API/11WI: page 1 of 1 Wellbore name: 0111-01 Well Header PermitlConcession N• 'Operator I ENI Share(%) 100.00'HOR Configuration type 402100 ENI PETROLEUM Rotary Table Elevation(ft) Ground Level(ft) 'Water Depth(ft) RKB-Base Flange(ft) I RKB-Tubing Spool(ft) 53,25 12.20 0.00 Rig Information Contractor 'Rig Name 'Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore 'Job Phase Spud Date 'Target Depth(ftKB) 'Target Depth(TVD...I Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) I DFS(days) 0111-01 DRILLING 9/22/2010 10,521.0 11,010.00 131.24 83.9 13.85 Daily Information End Depth(ftKB) End Depth(TVD)(1.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(•F) Weather Wild 6,370.0 3,668.4 904.00 21.13 42.8 84.0 28.6 Mostly Cloudy,WC 1°N Up 12.2 mph 18.3° Daily summary operation 24h Summary Finish displacing 9.0 cots LSND to 8.7 ppg FazePro. Drill out shoe track and 20'new hole to 6027'MD. CBU 8.7 ppg in and out. Pull up into 9-5/8"casing shoe and perform LOT,12.83 EWM @ 3652' TVD w/8.7 ppg FazePro and 784 psi. RD LOT equipment and drill 1/6027'V 6977'MD. Came out the top of OA1 Sand,made decision to sidetrack. POOH to 6380'MD. Begin troughing f/6414 V 6448' MD. Operation at 07.00 Unable to sidetrack at 6414'MD. Pulled up and began troughing f/6380 V 6400'MD. 24h Forecast Continue with openhole sidetrack. Drill ahead towards 8-112"Section TO at 10506'MD. Lithology 'Shows I MAASP Pressure(psi) I Mud Weight(lb/gal) 8.60 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Dsscr. 00:00 01:00 1,00 1.00 DRILL E 7 P Continue displacing 9.0 ppg LSND to 8.7 ppg Faze Pro OBM. 01:00 04:30 3.50 4.50 DRILL E 19 P Tag up on float collar at 5904'MD. Drill up plugs and float collar at 150-250 gpm,60-80 rpm,and 3-8 WOB. Lowering the flow rate from 450 gpm dramatically increased plug and float collar drilling efficiency. Drill out shoe track to 5991'MD. 04:30 05:00 0.50 5.00 DRILL E 3 P 'Drill 20'new hole f/6007'-6027'MD for LOT 05:00 06:00 1.00 6.00 DRILL E 7 P CBU at 500 gpm,1920 psi,80 rpm while reciprocating pipe. 8.7 ppg Faze Pro mud in and out. Pull up into 9-5/8"Casing / shoe. 06:00 07:00 1.00 7.00 DRILL E 19 P RU and chart LOT at 9-5/8"shoe @ 5990.9'MD/3652'TVD. RD and blowdown LOT equipment 10..6 -LOT:12.84 EMW with 8.7 coo FazePro and 784 oei W 3652'TVD 07:00 12:00 5.00 12.00 DRILL E 3 P Drill f/6027'-6348'MD.Backreaming every stand. -600 gpm,80-130 rpm,2-15K WOB -2300 psi ON/2290 psi OFF -8-9K TO ON/6-7K TO OFF -158 PU/118 SO1 130 ROB 12:00 20.30 8.50 20.50 DRILL E 3 P Drill f/6348'-6977'MD. Backreaming every stand. -650 gpm,130 rpm,2-15K WOB -2690 psi ON/2660 psi OFF -8K TO ON/6K TO OFF -162 PU/105 SO/128 ROB -MW:8.6 ppg,ECD.10,52 ppg 20:30 21:30 1.00 21.50 DRILL F 4 U Decision made to sidetrack. Came out of the top of the OA1 Sand. POOH 1/6997'V 6380'MD. 21:30 22:00 0.50 22.00 DRILL F 19 U Orient tools and take survey. 22:00 00:00 2.00 24.00 DRILL F 6 U Begin troughing f/6416'MD V 6448'MD. -620 gpm,80 rpm,6-7K TO,2340 psi Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Joe Longo Eni Petroleum Drilling Engineer Joe.Longo @enipetroleum.com 907-865-3323 907-947-4323 Eni representative Gary Goedich Eni Petroleum DrIg.Spvr. 907-670-8623 Eni representative Tom Norvig Eni Petroleum Rig Clerk 907-670-8607 907-229-6100 Eni representative Jack Potter Eni Petroleum HSE 907-685.1227 907-632-2236 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Mark Ashley Nabors Alaska Drilling Tool Pusher 807-670-8539 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 9 5/8 L80 -6,487,9 5,990.9 10/3/2010 Last Leakoff Test Depth(ftKB) I TVD(11KB) 'Fluid Type 'Fluid Density(lb/gal) IP Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 5,990.9 3,649.65 FazePro 8.70 784.0 12.84 2,433.5 Eni E&P Division Name:0111-01 OR ENI Petroleum Co.Inc. Daily Repo Well Code:25056 Field Name:Nikatchuq • Date:1016/2010' Report#: 18 APIIUWI: �� page 1 of 1 Wellbore name: 0111-01 Well Header Pemdt/Concession N° I Operator 'ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) !Ground Level(ft) 'Water Depth(ft) I RKB..Base Flange(ft) I RKB-Tubing Spool(ft) 53.25 12.20 0.00 Rig Information Contractor Rig Name 1Rig Type NABORS ALASKA NABORS 245E 1 LAND RIG Job Information Wellbore Job Phase I Spud Date I Target Depth(ftKB) 'Target Depth(ND..1 Depth Dr.(MD)(ft) Drilling Hours(hr) 'Avg ROP(ft/hr) I DFS(days) 0111-01 DRILLING 9/22/2010 10,521.0 11,010.00 131.24 83.9 14.85 Dally Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 7,118.0 3,682.0 748.00 4.92 152.0 84.0 25.3 Mostly Cloudy,WC 341°NNW cQ 14.5 12.7° mph Daily summary operation 24h Summary Unable to kick off on 1st sidetrack attempt. POOH for 2nd sidetrack attempt. Trough f/6378't/6403'MD. Experienced downtime due to top drive hydraulic unit,reset and continue 2nd sidetrack attempt. Time drill f/6304'-6305'MD with 2-4 WOB. Increase WOB to 5k and dropped into old hole. POOH for 3rd Sidetrack attempt. Trough from 6327'-6357'MD. Time drii f/6357'U 6370'MD. Drill f/6370' 1/7118'MD. Operation at 07.00 Currently Drilling Ahead at 7261'MD -620 gpm,130 rpm,200 fph -MW=8.7 ppg.EGO=10.19 EMW 24h Forecast Continue drilling ahead towards 8-1/2"Hole section TD©10506'MD Lithology 'Shows I MAASP Pressure(psi) 'Mud Weight(lb/gal) 8.70 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Decor. 00:00 02:30 2.50 2.50 DRILL F 3 U 1st sidetrack attempt unsuccessful. POOH to 6378'MD and begin troughing f/6378'MD to 6403'MD. -530 gpm,80 rpm - 000 psi ON -66000 ft-Ibs TQ ON 02:30 03,30 1.00 3.50 DRILL F 25 TR04 Down time due to top drive hydraulic unit. Reset PLC panel. Regained topdive rotation. 03:30 05:00 1.50 5.00 DRILL F 3 U Time drill f/6304'U 6305'MD with 2-4K WOB. Increased WOB to 6K and dropped into old hole. 05:00 09:00 4.00 9.00 DRILL F 3 U POOH one stand and begin 3rd Sidetrack attempt.Trough tom 6327'-6357'MD. -530 gpm,1780 psi -75 rpm,6100 TO 09:00 12:00 3.00 12.00 DRILL F 3 -U Time drill f/6357'-6363'MD at 1"every 2-1/2 min. -550 gpm,1825 psi -75 rpm,6500 TQ,2-4K WOB 12:00 14:30 2.50 14.50 DRILL E 3 U Time drill f/6363'-6370'MD at 2-4 fph. KOP•tp 6370'MD -550 gpm,1825 psi -75 rpm,7000 TQ 14:30 00:00 9.50 24.00 DRILL E 3 P Drill f/6370'MD to 7118'MD. -630 gpm,130 rpm,2-10 WOB,180-200 fph -2365/psi ON/OFF -8000/7000 ft-lbs TO ON/OFF -165 PU/100 SO/128 ROB -MW=8.7 ppg -EGO=10.21 EMW Daily Contacts Position Contact Name Company Title Eanall _ Office Mobile Eni representative Joe Longo Eni Petroleum Drilling Engineer Joe.Longo©enipetroleum.com 907-865.3323 907-947-4323 Eni representative Gary Goerlich Eni Petroleum Drlg.Spvr. 907-670-8623 Eni representative Tom Norvig Eni Petroleum Rig Clerk 907-670-8607 907-229-6100 Eni representative Jack Potter Eni Petroleum HSE 907.685-1227 907-632-2236 Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-8539 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(PKB) Bottom(RKB) Run Date CASING 9 5/8 L80 -6,487.9 5,990.9 10/3/2010 Last Leakoff Test Depth(ftKB) 'ND(ftKB) Fluid Type I Fluid Density(lb/gal) 'P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 5,990.9 3,649.65 FazePro 8.70 784.0 12.84 2,433.5 Eni E&P Division I Well Name:0111-01 OR EN! Daily Report Well Code:25056 Fil#1. Field Name:Nikatchuq e Date:10/7/2010 - Report#: 19 APVUVUI: page 1 of 1 Wellbore name: 0111-01 Well Header 402100 Concession N° IENI PETROLEUM (ENI Share(%) 100.00,HORIZON AL Configuration type Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) I RKB-Tubing Spool(ft) 53.25 12.20 0.00 Rig Information Contractor I Rig Name I Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore I Job Phase Spud Date !Target Depth(ftKB) 'Target Depth(TVD..I Depth Dr.(MD)(ft) I Drilling Hours(hr) Avg ROP(ft/hr) IDFS(days) 0111-01 DRILLING 9/22/2010 10,521.0 11,010.00 131.24 83.9 15.85 Daily Information End Depth(ftKB) End Depth(TVD)(t.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(•F) Weather Wind 9,310.0 3,707.2 2,192.00 15.78 139.0 84.0 12.7 Mostly Cloudy,WC- 172°S @ 13.4 mph 1.8° Daily summary operation 24h Summary Drill f/7118'MD t/9310'MD while backreaming every stand. -Total Footage Drilled-2192' -ADT-15.78 hrs Operation at 07.00 Currently Drilling Ahead at 9440'MD -630 gpm,130 rpm,200 fph -MW=8.7 ppg.ECD=10.25 EMW 24h Forecast Continue drilling ahead towards 8-1/2"Hole section TD rg 10506'MD. CBU+/-5x. BROOH to Intermediate casing shoe. CBU+/-2x. POOH LD BH,46. Test BOP Lithology 'Shows MAASP Pressure(psi) I Mud Weight(lb/gal) 8.70 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06:00 6.00 6.00 DRILL E 3 P Drilling ahead 1/7118'MD to 7885'MD backreaming every stand. -650 gpm,130 rpm,4-20 WOB,180-200 fph ^2400/2380 psi ON/OFF -9500/8000 ft-Ibs TQ ON/OFF -168 PU/98 SO/128 ROB -MW=8.7 ppg -ECD=10.4 EMW 06:00 12:00 6.00 12.00 DRILL 'E 3 P Drilling ahead 1/7885'MID to 8320'MD backreaming every stand. -630 gpm,130 rpm,2-15 WOB,180-200 fph -2550/2530 psi ON/OFF -9500/8500 ft-Ibs TO ON/OFF -170 PU/97 SO/130 ROB -MW=8.7 ppg -ECD=10.3 EMW 12:00 00:00 12.00 24.00 DRILL E 3 P Drilling ahead 1/8320'MD to 9310'MD backreaming every stand. ^630 gpm,130 rpm,4-10 WOB,180-200 fph -2740/2700 psi ON/OFF -9500/8700 ft-Ibs TO ON/OFF -180 PU/80 SO/120 ROB -MW=8.7 ppg -ECD=10.5 EMW Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Joe Longo Eni Petroleum Drilling Engineer Joe.Longo@enipetroleum.com 907-865-3323 907-947-4323 Eni representative Gary Goerlich Eni Petroleum DrIg.Spvr. 907-670-8623 Eni representative Tom Norvig Em Petroleum Rig Clerk 907-670-8607 907-229-6100 Eni representative Jack Potter Eni Petroleum HSE 907-685-1227 907-632-2236 Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-8539 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(ftKB). Run Date CASING 9 5/8 L80 -6,487.9 5,990.9 10/3/2010 Last Leakoff Test Depth(RKB) I TVD(ftKB) Fluid Type (Fluid Density(Ib/gal) IP Surf Applied(psi) I Eq.Mud Weight(lb/gal) I Leak Off Pressure(psi) 5,990.91 3,649.65 FazePro 8.70 784.0 12.84 2,433.5 Eni E&P Division (Well Name:0111-01 OR• ENI Petroleum Co.Inc. Daily Report Well Code:25056 Field Name:Nikatchuq • el .] Date:10/8/2010 - Report#: 20 API/ :UWI `�- page 1 of 1 Wellbore name: 0111-01 Well Header Pe Oit/Concession N• 'Operator PEoROLEUM I ENI Share(%) ' ell ZONTAL Configuration type Rotary Table Elevation(ft) Ground Level(ft) 'Water Depth(ft) RKB-Base Flange(ft) I RKB-Tubing Spool(ft) 53.25 12.20 0.00 Rig Information Contractor Rig Name I Rig Type NABORS ALASKA NABORS 245 E 1LAND RIG Job Information Wellbore Job Phase (Spud Date 'Target Depth(ftKB) 'Target Depth(TVD..'Depth Dr.(MD)(ft) 'Drilling Hours(hr) Avg ROP(ft/hr) I DFS(days) 0111-01 DRILLING 9/22/2010 10,521.0 11,010.00 131.24 83.9 16.85 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) 'Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 10,594.0 3,689.1 1,284.00 6.40 200.6 87.0 18.5 Mostly Cloudy,WC 186°S @ 9.4 mph 7.5° Daily summary operation 24h Summary Drill to 8-1/2"hole section TD ra 10,594'MD/3687.64'ND. CBU 4x at 630 gpm and 130 rpm while BROOH 1 stand per bottoms up. BROOH to 5910'MD. Begin circulating at intermediate casing shoe at 641 gpm and 80 rpm(no shocks encountered). Operation at 07.00 Operation©04:00 hrs. Currently POOH on elevators @ 2,450'MD. 24h Forecast Continue to POOH f/5910'MD on elevators and LD BHA#6. Test BOPS. PU Cleanout assembly BHA#7 and TIH to TD, CBU+/-2x. Short trip+/-10 stand to access swabbing. Spot 9.3 ppg Faze Away breaker and POOH. Lithology 'Shows MAASP Pressure(psi) 'Mud Weight(lb/gal) 8.70 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06:00 6.00 6.00 DRILL E 3 P Drill f/9310"MD 1/10000'MD,backreaming every stand. -630 gpm,130 rpm,4-20K WOB.200 fph -2730/2700 psi ON/OFF -10-12/9.5 K ft-Ibs TO ON/OFF -173 PU/88 SO/125 ROB -MW=8.7 ppg -ECD=10.50 EMW 06'00 11:30 5.50 11.50 DRILL E 3 P Drill 1/10000'MD U TO pt 10,594'MD/3687,64'11/D backreaming...very stand -630 gpm.130 rpm,4-6K WOB,200 fph -2930/2900 psi ON/OFF D • -10-12/9.5 K ft-Ibs TO ON/OFF -173 PU/88 SO/122 ROB -MW=8.7 ppg 'ECD=10.70 EMW 11:30 14:00 2.50 14.00'DRILL E 7 P CBU 4x at TD while BROOH 1 Stand every bottoms up. -630 gpm,130 rpm,9500 ft-Ibs TQ 14:00 23:00 9.00 23.00 DRILL E 4 P BROOH f/10118'MD U 5910'MD(Intermediate Casing Shoe©5991'MD). Noticed increase in torque and slight packing off at 9055'MD and 8065'MD. -630 gpm,130 rpm. 23:00 00:00 1.00 24.00 DRILL E 7 P Begin Circulating at shoe,no shocks to tools encountered. Noticed cement chucks during 1st bottoms up. • • -641 gpm,2250 psi,80 rpm,6000 ft-Ibs TO Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative -Joe Longo Eni Petroleum Drilling Engineer Joe.Longoienipetroleum.com 907-865-3323 907-947-4323 Eni representative David Smith Eni Petroleum Drig.Spvr. 907-670-8623 907-632-3058 Eni representative Bemie Leas Eni Petroleum Rig Clerk 907-670-8607 907-575-9427 Eni representative Jack Potter Eni Petroleum HSE 907-685-1227 907-632-2236 Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-8539 Eni representative Marc Kuck Eni Petroleum Completion Eng, Last Casing seat Cas.Type OD(in) I ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 9 5/8 f L80 -6,487.9 5,990.9 10/3/2010 Last Leakoff Test 1 Depth(ftKB) I TVD(ftKB) 'Fluid Type 'Fluid Density(Iblgal) I P Surf Applied(psi) Eq.Mud Weight(lb/gal) I Leak Off Pressure(psi) 5,990.9 3,649.65 FazePro 8.70 784.0 12.84 2,433.5 I • • 1 fkijil Eni E&P Division 'Well Name:0111-01 OR EN!Petroleum Co.Inc. Daily Report Well Code:25056 Field Name: Nikatchuq nil Date:10/9/2010 - Report#: 21 APguvM: "•- page 1 of 1 Wellbore name: 0111-01 Well Header Permit/Concession N• [Operator PEoROLEUM I ENI Share(%) 100.00'WOR Configuration type Rotary Table Elevation(ft) Ground Level(ft) 'Water Depth(ft) RKB-Base Flange(ft) I RKB-Tubing Spool(ft) 53.25 12.20 0.00 Rig Information Contractor Rig Name I Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore I Job Phase Spud Date !Target Depth(ftKB) !Target Depth(TVD..]Depth Dr.(MD)(ft) I Drilling Hours(hr) Avg ROP(ft/hr) I DFS(days) 0111-01 DRILLING 9/22/2010 10,521.0 11,010.00 131.24 83.9 17.85 Daily Information End Depth(RKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB - ' -' Temperature(•F) Weather Wind '.' 10,594.0 3,689.1 0.00 90.0 22.3 Cloudy,Light Snow. 27°NNE(&9.6 mph WC 11.8° Daily summary operation 24h Summary Continue to circulate at 5910'MD,CBU 3x. POOH on elevators, LD BHA#6. Pull wear ring,fill slack and choke manifold. Test Annular to 250/2500 psi-Good Test. Test BOPE and choke manifold to 250/3500 psi-Good Test. LD test joint and clear floor. PU cleanout assembly BHA#7 and TIH to 2718'MD Operation at 07.00 Operation©04:00 hrs. Currently Slip and Cut drilling line. 24h Forecast • Continue TIH Cleanout Assembly BHA#7 to Intermediate Casing Shoe. Slip and Cut. TIH to 10594'MD. Circulate hole clean. 15 stand short trip to asses swabing. CBU.Spot 9.3 ppg Faze Away breaker. POOH on elevators Lithology I Shows MAASP Pressure(psi) I Mud Weight(Iblgal) 8.70 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr.. 00:00 01:30 1.50 1.50 DRILL E 7 P Continue CBU 30 at 5910'MD. -640 gpm,2230 psi,80 rpm,6K TQ 01:30 05:00 3.50 5.00 DRILL 'E 4 P POOH on elevators V 5910'MD-477'MD. Take SLM on way out of hole. -Pulling Speeds -90 sec.per stand f/5910'MD V 4000'MD -60 sec.per stand f/4000'MD V 477'MD 05:00 08:30 3.50 8.50 DRILL E 5 P LD 8-1/2"Xceed675 BHA#6 and clear floor. 08:30 10:00 1.50 10.00 DRILL E 19 P Change out saver sub on top drive. • 10:00 12:00 2.00 12.00 DRILL E 5 P Pull wear bushing and RU to test BOPE. Fit BOPE and choke with water. 12:00 20:30 8.50 20.50 DRILL 'E 12 P Test annular preventer to 250/2500 psi-Good Test. Test BOPE equipment and choke manifold to 250/3500 psi-Good is p P Test. BOPE test witnessing waived by Lou Grimaldi AOGCC. 20:30 22:00 1.50 22.00 DRILL E 5 P Pull test plug and set wear ring. Blow down lines,drain stack,and clean rig floor. 22:00 22:30 0.50 22.50 DRILL E 5 P PU 8-1/2"cleanout assembly BHA#7 22:30 00:00 1.50 24.00 DRILL E 4 P TIH V 2718'MD. -100 PU/95 SO Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Joe Longo Eni Petroleum Drilling Engineer Joe.Longo @enipetroleum.com 907-865-3323 907-947-4323 Em representative David Smith Eni Petroleum DrIg.Spvr. 907.670.8623 907-632-3058 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-670-8607 907-575-9427 Eni representative Jack Potter Eni Petroleum HSE 907-685-1227 907-632-2236 Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-8539 Eni representative Marc Kuck Eni Petroleum Completion Eng. : Eni representative Michael Seward Eni Petroleum Project Advisor Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Rum Date CASING 9 5/8 LBO -6,487.9 5,990.9 10/3/2010 Last Leakoff Test Depth(RKB) /TVD(ftKB) Fluid Type !Fluid Density(lb/gal) !P Surf Applied(psi) I Eq.Mud Weight(lb/gal) I Leak Off Pressure(psi) 5,990.9 3,649.65 FazePro 8.70 784.0 12.84 2,433.5 Eni E&P Division Well Name:0111-01 OR ENI Petroleum Co.Inc. Daily Report Well Code:25056 Field Name:Nikatchuq • Date:10/10/2010 - Report#: 22 APIIUWI: I, page 1 of 1 Wellbore name: 0111-01 Well Header Pe OitConcession N° [Operator PEoROLEUM I EN1 Share(%) 100.00!WOR Configuration type Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) IRKB-Tubing Spool(ft) 53,25 12.201 0.00 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date [Target Depth(RKB) !Target Depth(ND...I Depth Dr.(MD)(ft) I Drilling Hours(hr) Avg ROP(ft/hr) 'DFS(days) 0111-01 DRILLING 9/22/2010 10,521.0 11,010.00 131.24 83.9 18.85 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB ."'' .' .. Temperature(°F) Weather Wind 10,594.0 3,689.1 0.00 90.0 23.4 Increaseing Clouds, 355°N a 15.9 mph WC 10.2° Daily summary operation 24h Summary TIH to 5942'MD. Cut and Slip drilling line. Wash and ream to bottom if 5942'MD V 10594'MD. Encountered several tight spots,max overpull 50 K. CBU 1.5x,pump 40 bbls 10.0 ppg weighted sweep, and circulate until clean. Attempt to pull on elevators,well swabbing. BROOH 11 10347'MD V 8910'MD. CBU 4x until shakers cleaned up,racking back 1 stand per bottoms up. Pump dry job and begin POOH to Intermediate Casing shoe t 5991'MD. Operation at 07.00 Operation @ 04:00 hrs. Cumenty POOH on elevators®5,939'MD 24h Forecast Continue to POOH on elevators to Intermediate Casing shoe. TIH to TD®10594'MD and condition Faze Pro. Pump 330 bbls 9.3 ppg Faze Away and POOH. LD Cleanout assembly BHA#7 and RU to run 5-1/2"15.5#L80 Hydril 521 Liner. Lithology Shows I MAASP Pressure(psi) 'Mud Weight(lb/gal) 8.70 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr, 00:00 02:00 2.00 2.00 DRILL E 4 P TIH V 2718'MD t/5942'MD on elevators. 02:00 03:00 1,00 3.00 DRILL E 19 P Slip and cut 81'drilling line. 03:00 04:00 1.00 4.00 DRILL E 19 P Service top drive,drawwnrks,and crown. CO oil filter on top drive 04:00 13:00 9.00 13.00 DRILL E 4 P Attempt to TIH on elevators f/5942'MD V TD®10594'MD. Encountered multiple tight spots on trip in. Most likely due to ✓ overstabilized BHA,lost retums or pack offs were not encountered. -6978'MD-Set 30 K down. Break circulation,unable to rotate. Pull 50 K overpull,jars hit,came free. -Wash and ream if 6978'MD V 6996'MD-380 gpm,750 psi.,40 rpm -TIN on elevators if 6996'MD V 7435'MD -Wash and ream fl 7435'MD V 7570'MD-360 gpm,740 psi,40 rpm,5-9 K ft-lbs TO -Wash f/7570'MD V 7819'MD -TIH on elevators f/7819'M131/8683 -Wash and ream f/8683'MD V 8815'MD-360 gpm,880 psi,70 rpm,8-9 K ft-lbs TQ. -TIH on elevators f/8815'MD V 9468'MD -Wash and ream f/9468'MD V 9485'MD-360 gpm,880 psi,70 rpm,8-9 K it-Ibs TO. -TIH on elevators f/9485'MD V 9677'MD -Wash and ream fl 9677'MD V 10594'MD-360 gpm,1000 psi,70 rpm,8-9 K ft-lbs TO. 13:00 16:30 . 3.50 ' 16.50 DRILL E 7 P CBU 1.5x. Pump 40 bbls 10.0 ppg weighted sweep. Circulate hole clean,CBU 5.5x total. -600 gpm,2400 psi -130 rpm,9-10 K ft-Ibs TO 16:30 20:00 3.50 20.00 DRILL E 4 P Attempt to POOH on elevators. Well swabbing. Pump out of hole f/10594'MD V 10347'MD. BROOH f/10347'MD V 8910'MD. -525 gpm,1780 psi -130 rpm,10 K ft-lbs TO -172 PU,80 SO a 10594'MD 20:00 23:00 3.00 23.00 DRILL E 7 P CBU 4x until shakers cleaned up,racking back 1 stand per bottoms up. -520 gpm,1650 psi -130 rpm,8-9 K ft-Ibs TO 23:00 00:00 1.00 24.00 DRILL E 4 P Flow check well-No Flow. Pull 1 stand,check for swabbing-No Swabbing. Pump dry job and begin to POOH on elevators,no swabbing encountered. -160 PU,80 SO Daily Contacts Position Contact Name Company Tide E-mail _ Office Mobile Eni representative Joe Longo -Eni Petroleum Drilling Engineer Joe.Longo2enipetroleum.com 907-865-3323 907-947-4323 Eni representative David Smith Eni Petroleum Drig.Spvr. 907-670-8623 907-632-3058 Eni representative Bemie Leas Eni Petroleum Rig Clerk 907-670-8607 907-575-9427 Eni representative Jack Potter Eni Petroleum HSE 907-685-1227 907-632-2236 Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Toot Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-8539 Eni representative Marc Kuck Eni Petroleum Completion Eng. Eni representative Michael Seward •Eni Petroleum Project Advisor Last Casing seat Cas.Type OD(in) ID(In) Grade I Top(RKB) Bottom(RKB) Run Date CASING 9 5/8 L80 -6,487.9 5,990.9 10/3/2010 Last Leakoff Test Depth(ftKB) I TVD(ftKB) [Fluid Type 'Fluid Density(Iblgal) I P Surf Applied(psi) I Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 5,990.9 3,649.65 FazePro _ _ 8.70 784.0 12.84 2,433.5 • fri# Eni E&P Division Name:OA1-0i OR ENI Petroleum Co.Inc. Daily Report Well Code:25056 Field Name:Nikatchuq • Date:10/11/2010 • Report#: 23 en API/UW: page 1 of 1 Wellbore name: 0111-01 Well Header 402100 Concession N° I ENI PETROLEUM I ENI Share(%) 100.001 HORIZONTAL Configuration type Rotary Table Elevation(ft) Ground Level(ft) 'Water Depth(ft) I RKB-Base Flange(ft) I RKB-Tubing Spool(ft) 53.25 12.20 0.00 Rig Information Contractor Rig Name Rig Type NABORS ALASKA I NABORS 245 E I LAND RIG Job Information Wellbore 'Job Phase (Spud Date 'Target Depth(ftKB) 'Target Depth(TVD...I Depth Dr.(MD)(ft) Drilling Hours(hr) 'Avg ROP(ft/hr) IDFS(days) 0111-01 DRILLING 9/22/2010 10,521.0 11,010.00 131.24 83.9 19.85 Daily Information End Depth(ftKB) 'End Depth(TVD)(f..'Depth Progress(ft) 'Drilling Hours(hr) 'Avg ROP(ft/hr) I POB I Temperature(°F) Weather II/And 10,594.0 3,689.1 0.00 92.0 24.4 Cloudy WC 12.2° 16°NNE(g114 mph Daily summary operation 24h Summary Continue to POOH on elevators f/8241'MD V 5942'MD. Encoutered a few tight spots @ 6736'MD,6447'MD,and 6375'MD. TIH 1/5942'MD to 10594'MD without issues. CBU 7x while conditioning FazePro and mixing FazeAway breaker fluid. Pump 338 bbls FazeAway and displace with 38 bbl 9.1 ppg FazePro followed by 20 bbls 11.0 ppg slug. Drop rabbit and POOH on elevators without issue. LD cleanout assembly BHA#7 and RU GBR Casing running equipment. Operation at 07.00 Operation(d 04:00 hrs. TIH 5-1/2"15.5#L80 Hydnl 521 Slotted/Blank Liner @ 786'MD. 24h Forecast Continue to Run 120 jts.5-1/2"15.5#L80 Hydril 521 Slotted/Blank Liner and 3 Swell Packers. Set liner hanger and displace to 9.0 ppg Inhibited brine. Lithology I Shows MAASP Pressure(psi) 'Mud Weight(lb/gal) 9.10 Time Log Start End Cum Time Time Our(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 03:30 3.50 3.50 DRILL E 4 P Continue POOH on elevators f/8241'MD V 5942'MD. Worked thru the following tight spots: -6737'MD-50 K overpull.Attempted to pull 4x. Backreamed thru Q 300 gpm,600 psi,80 rpm,6K ft-lbs TQ. Ran back with no pumps or rotary,no issues. -6447'MD-40 K overpull,worked thru no pumps or rotary. -6375'MD-40 K overpull,Backreamed thru @ 300 gpm,580 psi,80 rpm,6 K ft-Ibs TQ. Ran back thru without pumps or rotary,no issues. 03:30 04:00 0.50 4.00 DRILL E 19 P Clean rig floor and monitor well,static. 04:00 07:00 3.00 7.00 DRILL 'E 4 P TIH on elevators II 5942'MD V 10594'MD. Set down 30K at 9080'MD,worked thru 3x without pumps or rotary,no issues. 07:00 13:30 6.50 13.50 DRILL E 7 P CBU 7x while conditioning mud and mixing Faze Away breaker fluid. -450 gpm,1370 psi, 130 rpm / -10 K ft-lbs TO -110 PU/105 SO/108 ROB 13:30 16:00 2.50 16.00 DRILL E 7 P Displace 9.1ppg FazePro with 9.3ppg FazeAway breaker fluid. Pumped a total of 338 bbls, Displaced with 38 bbls FazePro mud and 20 bbls 11.0 ppg Slug. 16:00 23:00 7.00 23.00 DRILL E 4 P Drop 2.4"rabbit and POOH on elevators V 10594 V 323'MD. No issues. 23:00 23:30 0.50 23.50 DRILL E 5 P LD cleanout assembly BHA#7 and establish loss rate of 8 bph. 23:30 00:00 0.50 24.00 DRILL G 5 P RU GBR casing running equipment and prepare to run 120 As 5-1/2"15.5#L80 Hydril 521 Slotted/Blank Liner. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Joe Longo Eni Petroleum Drilling Engineer Joe.Longo@enipetroleum.com 907-865-3323 907-947-4323 Eni representative David Smith Eni Petroleum Drlg.Spvr. 907-670-8623 907-632-3058 Eni representative Bemie Leas Eni Petroleum Rig Clerk 907-670-8607 907-575-9427 Eni representative Mike Nelson Eni Petroleum HSE Eni representative Alvin Criswe8 Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-8539 Eni representative Marc Kuck Eni Petroleum Completion Eng. Eni representative Michael Seward Eni Petroleum Project Advisor Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 9 5/8 L80 -6,487.9 5,990.9 10/3/2010 Last Leakoff Test Depth(ftKB) I TVD(ftKB) Fluid Type I Fluid Density(lb/gal) IP Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 5,990.9 3,649.65 FazePro 8.70 784.0 12.84 2,433.5 roil, Eni E&P Division 'wen Name:oii -01 OR • ENI Petroleum Co.Inc. Daily Report Wen cede:25056 Field Name:Nikatchuq ei Date:10/12/2010 - Report#: 24 API/UWI: I � page 1 of 1 Wellbore name: 0111-01 Well Header Permit/Concession N° 'Operator NPEoROLEUM I ENI Share(%) 100.00'HORIZONTAL Configuration type 402100 Rotary Table Elevation(ft) Ground Level(ft) 'Water Depth(ft) I RKB-Base Flange(ft) IRKS-Tubing Spool(ft) 53.25 12.20 0.00 Rig Information Contractor I Rig Name Rig Type NABORS ALASKA NABORS 245 E 'LAND RIG Job Information Wellbpre Job Phase Spud Date 'Target Depth(ftKB) 'Target Depth(TVD..I Depth Dr.(MD)(ft) Drilling Hours(hr) !Avg ROP(ft/hr) I DFS(days) 0111-01 DRILLING 9/22/2010 10,521.0 11,010.00 131.24 83.9 20.85 Daily Information End Depth(ftKB) 'End Depth(ND)(f..'Depth Progress(ft) 'Drilling Hours(hr) 'Avg ROP(ft/hr) I POB I Temperature(°F) Weather 'Wed 10,594.0 3,689.1 0.00 87.0 24.4 Cloudy WC 12.2° 20°NNE @ 14 mph Daily summary operation 24h Summary Continue RU GBR Casing running equipment. Run 120 jts 5-1/2"15.5#L80 H ril 521 Slotted/Blank Liner and 3 swell packers on 5-1/2"DP to 10594'MD TOL(®5772'MD Oren hall and set liner hanger,test backside to 1500 psi for 10 mm-t,o00 Test.Began . Operation at 07.00 Operation©04:00 hrs. Currenity POOH LD DP 24h Forecast Continue to POOH LD DP. TIH 51 Stands out of derrick and displace to 9.0 ppg Inhibited Brine. POOH LD DP. RU SLB Eline and Run CBL. RD SLB Wilreline and prepare for 3-1/2"x 4.1/2"Innerstring completion. Lithology I Shows I MAASP Pressure(psi) 'Mud Weight(Iblgal) 9.10 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 01:30 1.50 1.50 DRILL G 5 P Continue RU GBR Casing running equipment. MU TIW on 5-1/2"Blank joint and hang on beaver slide. 01:30 02:00 0.50 2.00 DRILL G 1 P PJSM on PU 5-1/2"Slotted Liner. 02:00 . 12:00 10.00 12.00 DRILL G 4 P Run 120 Jts.5-1/2"15.5#L80 Hydril 521 Slotted alternating Blank Liner(58 Slotted/62 Blank)and a total 013 water swellable swell packers previously bucked up on 5-1/2"17#L80 Hydril 521 12'pups. MU and baker lock 5-1/2"Silver Bullet guide shoe to 10,000 ft-lbs. Torqued A.#1 to 16500 ft-Ibs and egged the box end on Jt.#1 and pin end on Jt.#2. Decision made to continue TIH,inner string will not be run to total depth. Torqued Jt.#2-4 to 6000 ft-Ibs,no problem. • Torqued Jt.5 to 12500 ft-lbs,to asses max torque capability prior to reaching depth at which inner string will be run to, egged box end of Jt.5 and pin end of Jt.6. Broke out and drifted to 4.825",OK, I Followed the Mowing torque strategy: -Jts.7-25:6000 it-Ibs -Jts.26-88:10000 ft-Ibs -Jts.89-120:12500 9-Ibs Noticed"dents"on the pin ends of Jts.94-96,due to donut thread protector hinge impacting the protector when coming into / • contact with the skate. Filed and drifted pin ends and MU without issues. Stopped using donut thread protector and began ✓/ using casing thread protectors Centralizer Placement. -Jts 1-100:5-1/2"x 7"Tesco Hydroforms tempted on. -Jts 101-116:5-12"x 7-5/8"Weatherford Spiralgliders. 12.00 13:00 1.00 13.00 DRILL G 1 P RD GBR Casing running equipment and fl tie back sleeve with pal mix. 13:00 17:30 4.50 17.50 DRILL G 4 P TIH with 5-1/2"Liner on 5"DP to TO(cB 10594'MD.TOL 5772'MD -Final Casing Run FF:0.18 CH/0.30 OH -165 PU/102 SO/135 ROB 17:30 19:30 2.00 19.50 DRILL G 5 P Circulate DP volume© 4 bpm,320 psi. Drop ball and pump onto seat. Set packer and test and chart backside to 1500 psi for 10 min-Good Test. 19:30 00:00 4.50 24.00 DRILL E 4 'P Begin POOH LD DP. Daily Contacts • Position Contact Name Company Title E-mail Office Mobile Eni representative Joe Longo Eni Petroleum Drilling Engineer Joe.Longo©enipetroleum.com 907-865-3323 907-947-4323 Eni representative David Smith Eni Petroleum Orig.Spvr. 907-670-8623 907-632-3058 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-670-8607 907-575-9427 Eni representative Mike Nelson Eni Petroleum HSE Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-8539 Eni representative Marc Kuck Eni Petroleum Completion Eng. Eni representative Michael Seward . Eni Petroleum Project Advisor Last Casing seat • Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(MKS) Run Date LINER 51/2 4.950 L80 -3,869.4 10,594.0 10/12/2010 Last Leakoff Test Depth(ftKB) IND(ftKB) Fluid Type 'Fluid Density(lb/gal) IP Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 5,990.9 3,649.65 FazePro 8.70 784.0 12.84 2,433.5 I • l V#41 Eni E&P Division 'Well Name:on 1-01 OR EN!Petroleum Co.Inc. Daily Report Well Code:25056 Field Name:Nikatchuq • APIIl1VN: enn Date:10/13/2010 - Report#: 25 II page 1 of 1 Wellbore name: 0111-01 Well Header 402100 Concession M 'Operator ENI PETROLEUM I ENI Share(A) 100.00!ORIZONTALation type Rotary Table Elevation(ft) I Ground Level(ft) [Water Depth(ft) I RKB-Base Flange(ft) I RKB-Tubing Spool(ft) 53.25 12.20 0.00 Rig Information Contractor Rig Name I Rig Type NABORS ALASKA NABORS 245 E I LAND RIG Job Information Wellbore Job Phase 'Spud Date 'Target Depth(ftKB) !Target Depth(TVD..J Depth Dr.(MD)(ft) Drilling Hours(hr) !Avg ROP(ftlhr) I DFS(days) 0111-01 DRILLING 9/22/2010 10,521.0 11,010.00 131.24 83.9 21.06 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) 'Drilling Hours(hr) 'Avg ROP(ft/hr) I POB Temperature(°F) !Weather !Wind 10,594.0 3,689.1 0.00 94.0 25.2 Cloudy WC 15.4° 38°NE @ 11.3 mph Daily summary operation 24h Summary Continue POOH LD DP. LD Liner running tool and release rig to completion 10/13/2010 05:00 hrs Operation at 07.00 Released Rig to Completion 10/13/2010 05:00 hrs 24h Forecast Released Rig to Completion 10/13/2010 05:00 hrs Lithology I Shows MAASP Pressure(psi) I Mud Weight(1b/gall 9.10 Time Log Start. End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 05:00 5.00 5.00 DRILL E 4 P Continue POOH LD DP 0 2873'MD. LD Liner runnning tool and release to completion,10/13/2010 05:00 hrs. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Joe Longo Eni Petroleum Drilling Engineer Joe.Longo @enipetroleum.com 907-865-3323 907-947-4323 / Eni representative David Smith Eni Petroleum Drig.Spvr. 907-670-8623 907-632-3058 ✓ Eni representative Bemie Leas Eni Petroleum Rig Clerk 907-670-8607 907-575-9427 Eni representative Mike Nelson Eni Petroleum HSE Eni representative Alvin Cns ell Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-8539 Eni representative Marc Kuck Eni Petroleum Completion Eng. Eni representative Michael Seward Eni Petroleum Project Advisor Last Casing seat • Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(f1KB) Run Date LINER 51/2 4.950 L80 -3,869.4 10,594,0 10/12/2010 Last Leakoff Test Depth(RKB) I TVD(ftKB) I Fluid Type !Fluid Density(lblgal) IP Surf Applied(psi) I Eq.Mud Weight(lblgal) Leak Off Pressure(psi) 5,990.91 3,649.65 FazePro 8.70 784.0 12.84 2,433.5 "' } Eni E&P Division Well Name:0111-01 OR ENI Petroleum Co.Inc. Daily Report Well Code:25056 Field Name:Nikatchuq • Date:10113/2010 - Report#: 1 API/UWI: �� page 1 of 1 Wellbore name: 0111-01 Well Header Permit/Concession N° 'Operator I ENI Share(%) Well Configuration type 402100 IENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) 'Water Depth(ft) I RKB-Base Flange(ft) 'RKB-Tubing Spool(ft) 53.25 12.201 0.00 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E !LAND RIG Job Information Wellbore 'Job Phase Spud Date 'Target Depth(ftKB) 'Target Depth(TVD..I Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) I DFS(days) 0111-01 COMPLETION 10,521.01 21.67 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 0.0 92.0 25.2 Increasing Clouds, 16°NNE @ 11.3 WC 14.5° mph Daily summary operation 24h Summary TIH t/5769'MD and displace well to 9.0 ppg Inhibited Brine. Had 8 bbl spill to containment and 40 gal spill out of containment due to plugged knife valve on overboard line to slop tank inadvertently overfilling CCB. Clean shakers and ditch. Circulate and balance well. POOH LD DP(181 jts.). RU SLB E-line and begin RIH with USIT/CBL. Operation at 07.00 Operation @ 04:00 hrs. Currently making second pass on USIT/CBL Log. Estimated TOC @ 3725'MD 24h Forecast Continue with E-Line logs(USIT/CBL). RD SLB E-Line and clear floor. RU SLB/Halliburton Completion. RU GBR Casing running equipment Begin running 3-1/2"x 4-1/2"Innerstring Completion Lithology 'Shows MAASP Pressure(psi) I Mud Weight(Iblgal) 9.00 Time Log Start End Clan Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 05:00 08:00 3.00 3.00 DRILL K 4 P TIH t/5769'MD with 5"DP. 08:00 09:00 1.00 4.00 DRILL K 7 P Displace well to 9.0 ppg Inhibited Brine. Pump 20 bbls LVT,50 bbls Hi-Vis sweep,and 387 bbl 9.0 ppg Inhibited Brine. -620 gpm,740 psi,80 RPM -5K ft-Ibs TO -130 PU/100 SO/110 ROB 09:00 10:00 1.00 5.00 DRILL K 20 U Saley Inspection. While displacing well to Inhibited brine the Hi-Vis Sweep and interface was diverted to the slop tank. In doing so the knife valve plugged off diverting the flow from the slop tank shute to the CCB which overflowed and created a spill. Spilled 8 bbls to containment and 40 gallons outside of containment. Spillechs and saftey personnel were alerted and cleaned up promptly. 10:00 11:00 1.00 6.00 DRILL K 1 P Clean out shakers and ditches. 11:00 12:00 1.00 7.00 DRILL K 7 P Circulate and condition brine to balance well. 12:00 20:00 8.00 15.00 DRILL K 4 P POOH,LD DP(181 jts),and remove from pipe shed. 20:00 22:30 2.50 17.50 DRILL J 19 P RU SLB E-Line for USIT/CBL 22:30 00:00 1.50 19.00 DRILL K 19 P Begin RIH E-Line. Daily Contacts Position Contact Name Company Title Entail Office Mobile Eni representative Joe Longo Eni Petroleum Drilling Engineer Joe.Longo©enipetroleum.com 907-865-3323 907-947-4323 Eni representative David Smith Eni Petroleum Drlg.Spur. 907-670-8623 907-632-3058 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-670-8607 907-575-9427 Eni representative Mike Nelson Eni Petroleum HSE Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Eni representative Marc Kuck Eni Petroleum Completion Eng. Eni representative Michael Seward Eni Petroleum Project Advisor Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-8539 Eni representative Jack Keener Eni Petroleum Sr.Ddg.Spvr. Jack.Keener@enipetroleum.com 907-670-8623 907-715-6434 Last Casing seat Cas.Type OD(In) ID(In) Grade Top(RKB) Bottom(RKB) Run Date LINER 51/2 4.950 L80 -3,869.4 10,594.0 10/12/2010 Last Leakoff Test Depth(RKB) 'TVD(lIKB) (Fluid Type 'Fluid Density(lb/gal) 'P Surf Applied(psi) I Eq.Mud Weight(lb/gal) 'Leak Off Pressure(psi) 5,990.9 3,649.65 FazePro 8.70 784.0 12.84 2,433.5 • • "' Eni E&P Division I Well Name:0111-01 OR ENI Petroleum Co.Inc. Daily Report Well Code:25056 Field Name:Nikatchuq n Date:10/14/2010 - Report#: 2 APINW: t, " page 1 of 1 Wellbore name: 0111-01 Well Header Permit/Concession N° [Operator NPEoROLEUM I ENI Share(%) 100.001 HOR Configuration type Rotary Table Elevation(ft) Ground Level(ft) 'Water Depth(ft) I RKB-Base Flange(ft) I RKB-Tubing Spool(ft) 53.25 12.20 0.00 Rig Information Contractor 'Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase I Spud Date 'Target Depth(ftKB) 1 Target Depth(TVD..'Depth Dr.(MD)(ft) !Drilling Hours(hr) 'Avg ROP(ft/hr) I DFS(days) 0111-01 COMPLETION 10,521.01 22.67 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 0.0 93.0 23.4 Cloudy,WC 12.7° 57°ENE @ 14.3 mph Daily summary operation 24h Summary Continue running USIT/CBL on E-Line. Estimated TOC 3725'MD. POOH and RD SLB E-Line. Remove wear ring and clear floor. RU GBR Casing running equipment,SLB Completion,and Halliburton `' C Completion. Spot all completion equipment on rig floor and pipe shed. Begin running 3.1/2"9.2#LBO IBTM SCC x 4-1/2"12.6#L80 IBTM Innerstring completion. v` J Operation at 07.00 Operation @ 04:00 hrs. Currently Running 3-1/2"x 4-1/2"Innerstring Completion @ 3,578'MD. 24h Forecast Continue running 3-1/2-x 4-1/2"Innerstring Completion Lithology 'Shows MAASP Pressure(psi) 'Mud Weight(lb/gal) 9.00 Time Log Start End Cum Time Time Our(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06:00 6.00 6.00 DRILL J 19 P Continue running USIT/CBL. Estimated top of bonded cement 3725'MD,cement stringers up to 3520'MD. Top N Sand 5403'MD,TOC-1678'above. 06:00 07.30 1.50 7.50 DRILL J 5 P RD SLB E-Line. 07:30 08:00 0.50 8.00 DRILL K 1 P Pull wear bushing and clear rig floor for completion equipment. 08:00 15:00 7.00 15.00 DRILL K 1 P RU GBR casing running equipment. RU SLB/Helliburton Completions. Spot fiber optic and control line reels on rig floor and RU sheaves. Spot swell packer feed thru table,'CDs,and 3.112"and 4-1/2"Polyoil cable clamps. Bring all pups, XO's,and completion equipment in pipe shed. 15:00 00:00 9.00 24.00 DRILL K 4 P Begin running 56 of 111 jts.3-1/2"9.25 L80 IBTM SCC tubing and 11x11mm encapsulated FiberOptic line to 2337'MD. Tested Fiber line every 1000'-Good Test. Installed 6 of 12 Tejas ICDs(Inflow Control Device)and 1 of 3 water swellable EasyWell Swell Packers. -Avg MU TO 1500 ft-Ibs -65 PU/60 SO Daily Contacts Position Contact Name Company Title E-mail Office Mobile • Eni representative !Joe Longo Eni Petroleum Drilling Engineer !Joe.Longo @enipetroleum.com 907-865-3323 907-947-4323 Eni representative David Smith Eni Petroleum Orlg.Spvr. 907-670-8623 907-632-3058 Eni representative Bemie Leas Eni Petroleum Rig Clerk 907-670-8607 907-575-9427 Eni representative Mike Nelson Eni Petroleum HSE Eni representative Alvin Criswell Eni Petroleum Expediter 807-980-7545 Eni representative Marc Kuck Eni Petroleum Completion Eng. Eni representative Michael Seward Eni Petroleum Project Advisor Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-8539 Eni representative Jack Keener Eni Petroleum Sr.Ddg.Spvr. Jack.Keener @enipetroleum.com 907-670-8623 •907-715-6434 Last Casing seat Cas.Type ` OD(in) ID(in) Grade Top(RKB) Bottom(ftKB) Run Date LINER f 51/2 4.950 L80 -3,869.4 10,594.0 10/12/2010 Last Leakoff Test Depth(ftKB) 'TVD(ftKB) Fluid Type (Fluid Density(lb/gal) IP Surf Applied(psi) Eq.Mud Weight(lb/gal) 'Leak Ott Pressure(psi) 5,990.9 3,649.65 FazePro 8.70 784.0 12.84 2.433.5 • • • lirlAfill Eni E&P Division I Well Name:0111-01 OR EN/Petroleum Co.Inc. Daily Report Well Code:25056 Field Name:Nikatchuq Date:10/15/2010 - Report#: 3 API/tom: �� page 1 of 1 Wellbore name: 0111-01 Well Header Permit/Concession N° (Operator IENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) [Ground Level(ft) I Water Depth(ft) RKB-Base Flange(ft) I RKB-Tubing Spool(ft) 53.25 12.20 0.00 Rig Information Contractor Rig Name 1Rig Type NABORS ALASKA NABORS 245 E ILAND RIG Job Information Wellbore Job Phase 'Spud Date 'Target Depth(ftKB) !Target Depth(TVD..]Depth Dr.(MD)(ft) Drilling Hours(hr) 'Avg ROP(ftlhr) I DFS(days) OI11-01 COMPLETION 10,621.01 23.67 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 0.0 92.0 21.9 Cloudy.Light Snow. 71°ENE/3.8 mph WC:16.5° Daily summary operation 24h Summary P/U&RIH with 3"IBTM tbg.9.6#,L-80 Innerstnng. Install jewel as per tally 1/2337'-114644'\P/U Schlumberger gauge carrier,dress&test tech wire\Change to 4"handling equipment\RIH with 4"tbg. P/U X-nipple&Halliburton AHR Packer 1/4644'-1/4929'\Feed Tech wire(5400 psi test)&Fiber-optic(test)thru Halliburton Packer\Change spool/reels on rig floor\Schlumberger spliced Fiber-optic line, (required two splices,first one broke while installing outer housing).Test same(base line length 23,716')\Continue to P/U&RIH with 4"tbg.1/4929'-1/7083'installing poly clamps on every connection, Schlumberger test Fiber-optic in 6110'. Operation at 07.00 Operation at 0400 Hours: Picking up GLM. 24h t Forecas - - RIH w/4 1/2"Innerstring Completion 1 P/U tbg.hanger&land,test to 5000 psi.\Drop ball&rod assembly-pump to set packer\Shear DCK-2 valve in GLM\Install BPV&N/D BOP/N/U tree&test same with diesel/Freeze protect well with diesel. Lithology (Shows MAASP Pressure(psi) I Mud Weight(Ib/gal) 9.00 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Opel'.Descr. 00:00 08:00 8.00 8,00 COMP K 4 P P/U 3 1/2"IBTM tbg.-9.2#,L-80\Innerstnng completion 1/2337'-114644'\P/U 3 Halliburton swell packers-12 ICD w/pups \Installed 3 cannon clamps-62 SS bands-95 poly clamps\Schlumberger tested fiber-optics @ 2677',3723'&4644' before spice. 08:00 09:00 1.00 9.00 COMP K 4 P P/U Schlumberger gauge carrier sub and dress with gauge-test tech line\C/O elevators&slips to 4 1/2". 09:00 09.30 0.50- 9.50 COMP K 4 P P/U 4 1/2"IBT tbg.-12.6#,L-80\Innerstring completion 1/4644'-114929'\P/U X-nipple and Halliburton 4 1/2"x 9 5/8"AHR packer\Up wt.=71K-Dn wt.=68K. 09:30 12:00 2.50 12.00 COMP K 20 P Feed tech wire thru packer&spice some&test to 5400 psi-good test\Feed fiber-optic thru packer prep to make splice. 12:00 13:00 1.00 13.00 COMP K 20 P Change out Schlumberger fiber-optic spool/reel on rig floor. 13:00 18:00 5.00 18.00 COMP K 20 P Schlumberger prep to splice fiber-optic line-first splice broke when installing outer housing.Re-splice fiber-optic and install housing.Test same,good test.Base line length 23,716'. 18:00 00:00 6.00 24.00 COMP K 4 P Continue RIH 1/4929'-1/7083'\installing poly clamps on every collar\test Schlmberger(ri 6110'. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Jack Keener 'Eni Petroleum Sr.Drlg.Spvr. Jack.Keener(d)enipetroleum.com 907-670-8623 907-715-6434 Eni representative David Smith Eni Petroleum Drig.Spvr. 907-670-8623 907-632-3058 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-670-8607 907-575-9427 Eni representative Mike Nelson Eni Petroleum HSE Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Eni representative Marc Kuck Eni Petroleum Completion Eng. Eni representative Michael Seward Eni Petroleum Project Advisor Tool Push Bruce Simonson Nabors Alaska Drilkng Tool Pusher 907-670-8539 Last Casing seat Cas,Type I OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date LINER 5 1/2 4,950 L80 -3,869.4 10,594.0 10/12/2010 Last Leakoff Test Depth(ftKB) 'TVD(ftKB) 'Fluid Type 'Fluid Density(lb/gal) 'P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 5,990.9 3,649.65 FazePro 8.70 784.0 12.84 2,433.5 ■ • • Eni E&P Division well Name:0111-01 OR ENI Petroleum Co.Inc. Daily Report Well Code:25056 Field Name:Nikatchuq en Viiiiil•II, Date:10/16/2910 - Report 9: 4 AP°uH^: II �) page 1 of 1 Wellbore name: 0111-01 Well Header 402100 Concession N• 'Operator ENI PETROLEUM I EM Share(�) 100.00'HORIZONTAL Configuration type Rotary Table Elevation(ft) 'Ground Level(ft) 'Water Depth(ft) RKB-Base Flange(ft) I RKB-Tubing Spool(ft) 53.25 12.20 0.00 Rig Information Contractor 'Rig Name 'Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore 'Job Phase 'Spud Date 'Target Depth(ftKB) 'Target Depth(TVD..I Depth Dr.(MD)(ft) "Drilling Hours(hr) Avg ROP(ft/hr) IDFS(days) OI11-01 COMPLETION 10,521.01 24.67 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(•F) Weather Wind 0.0 90.0 25.3 Cloudy.WC 9° 12°NNE/28.1 mph Daily summary operation 24h Summary P/U&RIH with 4"tbg.f/7083'.1/8232'\GLM would not drift with 3.833"-Halliburton Rep got X-lock tool&drifted(3.813")-P/U GLM I Continue to P/U tbg.1/8250'-1/10339'\P/U tbg.hanger 8.landing joint-orientate to well head as per Vetco Gray Rep.\Dress tbg.hanger with tech wire,fiber-optic&penetrate I Land tbg.hanger- 3 1/2"tbg. @ 10378.50'\Test tbg.hanger seals to 5000 psi for 10 mins.1 L/D landing joint&install BPV I Clear floor of completion equipment\N/D BOPE. Operation at 07.00 1• N/D BOPE 24h Forecast N/D BOPE&N/U tree&test same to 500/5000 psi.I Test tbg.&shear out GLM\Freeze protect annulus\Install BPV&secure well I RDMO to OP23-W W02. Lithology 'Shows MAASP Pressure(psi) I Mud Weight(Iblgal) 9.00 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 03:00 3.00 3.00 COMP K 4 P P/U 4 1/2"IBTM tbg.-12.6#,L-80 Inter-string completion 1/7083'-1/8232'\Install poly clamps @ connection 1 Schlumberger tested fiber-optics©7610'. 03:00 06:00 3.00 6.00 COMP K 20 U P/U Schlumberger GLM attempt to drift with 3.833"drift and would not drift-L/D&remove drift-Halliburton Rep.got a X- lock slick line tool(3.813"OD)drift OK.P/U Schlumberger GLM and RIH. 06:00 12:00 6.00 12.00 COMP K 4 P P/U 4 1/2"IBT tbg.-12.6#,L-80 Innerstring completion(/8250'-I/10339'\Installing poly clamps 01 connection I P/U 3 joints VIT insulated tbg.\Up wt=101K-Dn wt.=66K.Schlumberger test tech wire&fiber-optic cables/t 8232'&9424'. 12:00 14:00 2.00 14.00 COMP K 20 P P/U Vetco Gray tbg.hanger&Landing joint-Orientate hanger to well head. 14:00 16:00 2.00 16.00 COMP K 20 P Vetco Gray&Schlumberger dressed hanger(feed thru)with tech wire,fiber-optic line&penetrate.Drain stack. 16:00 17:00 1.00 17.00 COMP K 20 P Land hanger as per Vetco Gray Rep-screw-in LDS and test lower&upper seals to 5000 psi for 10 minutes./Schlumberger tested tech wire&fiber-optic.3 1/2"tbg.®10378.50'. 17:00 20:00 3.00 20.00 COMP K 12 P Set Halliburton packer with 1.6 bbls.pumped @ 4000 psi.-hold pressure for 30 minutes,chart record.R/U on annulus (I.A.)and test to 500 psi for 15 mins.to confirm packer set. 20:00 21:00 1.00 21.00 COMP K 20 P L/D landing joint&install BPV as per Vetco Grey\R/D equipment on rig floor. 21:00 23:00 2.00 23.00 COMP K 2 P Clear floor of completion components\Schlumberger tech/fiber-optic reels,tool&equipment,R/U sheaves form derrick. 23:00 00:00 1.00 24.00 COMP K 5 P N/D BOPE. Daily Contacts . Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener Eni Petroleum Sr.Dag.Spvr. Jack.Keeneraenipetroleum.com 907-670-8623 907-715-6434 Eni representative David Smith Eni Petroleum Dag.Spvr. 907-670-8623 907-632-3058 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-670-8607 907-575-9427 Eni representative Mike Nelson Eni Petroleum HSE Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Eni representative Marc Kuck Eni Petroleum Completion Eng. Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-8539 Last Casing seat Cas.Type OD(in) ID(in) Grade .'Top(RKB) Bottom(ftKB) Run Date LINER 51/2 4.950 L80 -3,869.4 10,594.0 10/12/2010 Last Leakoff Test Depth(ftKB) I TVD(ftKB) Fluid Type 'Fluid Density(lb/gal) I P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 5,990.9 3,649.65 FazePro 8.70 784.0 12.84 2,433.5 • FAI°1 Eni E&P Division Ewen Name:0111-01 OR ENI Petroleum Co.Inc. Daily Report Well Code:25056 Field Name: Nikatchuq i Date:10/17/2010 • Report#: 5 API/UWI: "� page 1 of 1 Wellbore name: 0111-01 Well Header Permit/Concession N. 'Operator I ENI Share(14) Well Configuration type 402100 IENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) I Ground Level(ft) [Water Depth(ft) I RKB-Base Flange(ft) I RKB-Tubing Spool(ft) 53.25 12.20 0.00 Rig Information Contractor I Rig Name 'Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase I Spud Date 'Target Depth(ftKB) [Target Depth(TVD.. Depth Dr.(MD)(ft) •Drilling Hours(hr) 'Avg ROP(ft/hr) IDFS(days) 0111-01 COMPLETION 10,521.0 25.67 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(•F) Weather Wind 0.0 81.0 25.0 Cloudy.WC 6.6° 15°NNE©36.7 mph Daily summary operation 24h Summary N/D BOPE\Vetco Gray&Schlumberger prep tech wire&fiber-optic-feed thin tree flange\N/U tree-Test voids to 5000 psi f/10 minutes-test body&valves to 500/5000 psi.(chart recorded)1 Pressure -up on tbg.1/1500 psi;pressure test inner annulus to 2500 psi(chart recorded)1 Bleed off tbg.to shear DCK-2 valve in GLM.did not shear\ Pressure-up I.A.to 2900 psi.to shear./Freeze protect annulus pumped 160.5 bbls.@ 2 bpm FCP @ 1200 psi.O.A.@ 150 psi.\U-tube well 150 psi on&bleed to tbg.50 psi.-R/U Vetco Gray lubricator to install BPV,RID same&lines off tree,secure tree\RDMO off 0111-01. Operation at 07.00 Moving rig to well OP23-WW02. 24h Forecast RID move off OI11-01 to OP23-WW02 Lithology 'Shows I MAASP Pressure(psi) 'Mud Weight(lb/gal) 9.00 Time Log Start End Cum • Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. , 00:00 06:00 6.00 6.00 COMP K 5 P N/D BOPE-Clean out Katch-Kan&flow line,RID same\N/D Riser,BOPE set back on stump and remove lower riser-L/D same. 06:00 07:00 1.00 7.00 COMP K 5 'P Clean-up tbg.hanger top\Schlumberger Rep prep tech wire&fiber-optic for tree. 07:00 11:00 4.00 11.00 COMP K 5 'P N/U tree install tech wire&fiber-optic wire(splice)through tree flange,terminate same&test both as per Schlumberger Rep. 11:00 12:00 1.00 12.00 COMP K 5 P Install flow manifold&wing valve on tree-as per Vetco Gray-test tree voids to 5000 psi.for 10 mins. 12:00 14:00 2.00 14.00 COMP K 5 P R/U circulate manifold-Vetco Gray finished N/U. 14:00 16:00 2.00 16.00 COMP K 19 P Vetco Gray Rep pulled BPV&install two-way valve\Test tree body&valves to 500 psi for 5 mins.&5000 psi for 15 mins, , chart record all test. Alt 11_''�0 ' 16:00 19:00 3.00 19.00 COMP K 19 P R/U Little Red and test to 3000 psi.1 Pressure-up on tbg.to 1500 psi.&(I.A.)to 2500 psi.chart record for 30 mins.-bleed a" off tbg.to allow DCK-2 shear valve in GLM to open-bleed off tbg.to zero.Did not snear'bleea off(I.A.)an pressure-up to 2900 psi,sheared out.\Pump 160.5 bbls.of diesel to freeze protect-FCP 1200 psi @ 2 bpm.\125 psi on tbg.-monitor O.A.150 psi. 19:00 21:00 2.00 21.00 COMP K 19 P Let well U-tube with I.A.&tbg.@ 150 psi.\Bleed to tbg.50 psi.\R/U Vetco Gray lubricator and lubricated BPV in as per • Vetco Rep.R/U same. 21:00 22:00 1.00 22.00 COMP K 20 P Blow lines&R/D off tree-secure as per Vetco Gray Rep, 22:00 00:00 2.00 24.00 COMP K 20 P Prep for Rig move-R/D interconnects between modules,raise Dixie cup\Start-up Lampsons. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener Eni Petroleum Sr.Ddg.Spvr. Jack.Keener @enipetroleum.com 907-670-8623 907-715-6434 Eni representative David Smith Eni Petroleum Drlg.Spvr. 907-670-8623 907-632-3058 Eni representative Bemie Leas Eni Petroleum Rig Clerk 907-670-8607 907-575-9427 Eni representative Mike Nelson Eni Petroleum HSE Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-8539 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) - Bottom(ftKB) Run Date LINER 51/2 4.950 L80 -3,869.4 10,594.0 10/12/2010 Last Leakoff Test Depth(ftKB) I TVD(ftKB) Fluid Type 'Fluid Density(lb/gal) IP Surf Applied(psi) Eq.Mud Weight(lb/gal) I Leak Off Pressure(psi) 5,990.9 3,649.65 FazePro 8.70 784.0 12.84 2,433.5 • • �Vmapplpp2w§ npnpl(:pr�p"' rnppoppopp`R.� i°pp`sppinapp°'p_sp1p �pNN��aYp}i'`9i 0 ys,"g� n)mp)'`�'�cNl pv4�wpps J 80080008 2828 22282 000000 0 W 00 00 W 00 00 W 00 000 W S 4x444 41411 evade 41441 44414 11111 41414 v441 8 � a � WWpp M pa60 NMp O � p8 NN O 2 lOn CC) + 486 D N O p0 N O N.00 N , W 0) 3 ) ros 00000 55'688 000 NM ON N n pm m 8a 8 82 6 N. r N N N N N N N M M M a 6 a ..... 66010) ..... 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E r 'w O1pp pp (� Vj O W y E10')2 °006200)2 00 W NN 08100.2 :-“,',287,8(V3(300 218.822 �Opp(((000(°pp 1000(�Np 100p0 t8,(8pp topp(0pp N O u NN NNNNN 7'(07(077'7' MMtN+)0N0(7'7 MMM(7(107 7'12+)'202(� (7(7177'(7 177'1+11717 N 01 N :-. ,2 d 0 « 9 W > i '',"=8.1 MMQN1 o0ot0.- MM�MQ Na8�CO3) aND,h fNOn V (N'),(00,(107°r t7', 4(00.8 nn U �w q ~ E d d 1- cio 0 rp0 pN yQ Q0 pQMp000 p0p0 4'4604 010040) p_(Mp N y a_ App(2 048(QpN 100 Zp) E m7' SM17(7M (7t7C')AA t717AAA (()M(7'7M17 (")AAAA t7 C')(7MM t7M(7'7M2 O �1 (2 "1818 N Q "68 .z.9 ,2. `-'3 • LL ttttt Q Q) 0 Q Q Q Q Q J N 1 W G 0 W LL J W y w 0 y j 1C pp p p tp N(y( : ? t, h O N 1".:23 0 8000000 0 0)0)0000 00171001 888000 8881 N^ 100 N 00 000620 O N O N W 0 O U(1 28 888808 82880 0100(00 0(00(00 1010800 08000)00)00 20000 D 0 J 1+) N .0 in Y CC LL J E 01 W N U- 0 0 C u tv O 88 104 p p p(p p N C MN N 0 LL 1 2 F{OpEE (D17N8� t1722E88:2 (0,80(88fp0p8 ,718,1..t8pp0 84-,888 .8-((f8,-.2p(0 cA W N W O ~E(((8Nf000 i82 C h )117 V Q Y 00004 82-8,00 NN�ONN 882E8 10(0 2(0120 8(00�N(00 2 NN O)08) o m N(QN 1 a y W O J N a o E 4 0 0 0 2o• LL O 0(80 001 O co IQs '-NW( E ? wm F E O d d $ o E 2 2 a W a N 0, i N c J C c N N W N O Z J O - Z E O n U 9 9 Q 9 a 6 ws O N E C H 0 — C — U 14 F m � E E 0 U aro.* Oliktok Point Nikaitchuq Field anti 2rn1ti pth°oicu nr`n 0111 -01 Alaska DIR/LWD FORM DEPTH HOLE CASING MUD INFO Drilling MWD MD TVD SIZE SPECS Hazards Cement to Surface 20" Hole Angle X-65 0° 20"Conductor Shoe 160' 160' N/A Welded/Driven N/A 0 GR/Res v Surface Csq Dir 3 13-3/8" Base Permafrost 1,900' 1,778' > 68 lbs/ft MW(ppg) Wellbore Stability td Mud Motor r• L-80,BTC 8.8-9.5 Lost Circulation Hole Cleaning KOP:400' DLS: 1.5-3.5 deg/100' i Al Hole Angle 44 13-3/8"Casing Point 2,334' 2,160' 16" 50°F WBM GR/RES PWD Inter.Casinq Wellbore Stability 9-5/8" Lost Circulation Xceed 900 47 lbs/ft MW(ppg) Hole Cleaning L-80,BTC-M 8.8-9.5 Torque&Drag Sail Angles: 67 degrees a„aw Injection Packer 5,456' „ p'q ' ; p ly` Hole Angle 87 9-5/8"Casing Point 5,990' 3,653' r 12-1/4" 85°F LSND GR/RES PWD Wellbore Stability Option to run sonic Lost Circulation for int.casing CBL Schrader Bluff Slotted Liner Hole Cleaning Lateral 5-1/2" Torque&Drag 17 lbs/ft MW(P139) Xceed 675 L-80 8.8-9.0 (Geo-Steering) Hydril 521 5-1/2"Slotted Liner Hole Angle 94 TD/5-1/2"Lnr 10,594' 3,689' 8-1/2" 85"F MOBM , . • p ,_,, - /04, . •MEC i, R7 CA.7 f EGRITY RFPPDRT • •. . ?Up D t.=E : -• UZzi/O OPER E FIELD .. ..,�- ):l" Al/Ca f ck, RIG R LEASE : • /0//Z W L NUM ER .�.. .�0I if - O f.�._.Cw r 5) wt LL DATA 'A) I /059y.k4.. 3687 TvD., 1-- TD P : /o s7Y 34,8 7 IVA / 34Vur1asin 3 ' $1os,: a33Yry 2C6 ; DV : - .: TV s"'� 5- -- ` g sboe : o .Yll T ; O : HD vr-D uo g : :.- P€ckc= _._ KO TVl7 ; Set. at '.z.._ ,.._ .. oi.w Si ^a • and ; P rfs to . p! ':1'CRAM:CAL INTEGRITY. -- PART ;1 k le, • Amnuiu.s ?rrss Test: 73 25001 15 taxza ; 0 mini ?'�, C otnmcn t s : • -l. � t –14-- __4-60 - /017 /o •..ea...� CBAN ICAL INTEGRITY - PART !2 ..—°.� ..1 BBL Cement Voi cs r Axxt. U.—tr Cat 2/l DV Cmt von, to cover per ,s FO aizr .fie., �+ .,,__, -mc_,.a- -=c-s.-ma, .1.7.1 .r 4,—st-r^.n.s•s.tsz.r.:;aa. .._...t Theore ticz.l TOC 369° kc:c,.4_ 4.4- ,,36 f Of •.0 ,.e.... Cement Bond. La:Aar.of No) D'- ; In AOGCC File_�� Gl Lc✓.© soak CSI. Evaltmtion 4 zone above parfs o e - L;)„,,,�,t,c. - c -,,,,-,,i,1 4-f s v ' ''t �. Prod.0 .tfon Log: Type A- ; Evalu&tion CONCLUSIONS : • 5 it t #1 : ,j0.-Pit e-ss'e..0 /�. .. – l f1 a ' c r s s://2....0 i,44Q _,e„_ • art /2 :. C:e. ..f_ ,ts.,..,9 �.6. .... I�l� - 12, i-__ S � oz�,� . /13-// Schlumberger Private L CLD L E E \ i eJ O O ti S.? I .L—... lZ \2 cu = F— cs) O CU CI 0 = U •INIM■ Z 0 = > O o � w — co co CI) N o - ° U— 0 Q C a� O = > .El.. =, E . _ c) . ct, = E 'Z — 0) p � cm w O C, cn N o c.) 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Cl) CO '4— a) a ? � C 0 a) a) C O c) +-+ +-, co co E E 'CL CV 2 L 2 =_ co, Q Q a) co co -0 O O -1--,O �O C -0 CD- C ~ I. � -0 O 0 = . a) -a a) E 0 '0 O = o — C a) I- •— C � '� Cr) cn CD C — = > co •— - 0 U = co 0 '� C� C/) C a'--+ C/) a) ON = C a) p O '� E o E •a; cn " O O O CO Q E O� � ca C C O O O O }, a) a) � z Q a Cam) Cl)/ I— p E a) z z = cam w 0 0 > .� Co > > }' C E •a' O E o o n No C U o N o Schlumberger Drilling&Measurements MWD/LWD Log Product Delivery Customer ENI US Operating Co.Inc.Alaska Dispatched To: Christine Shartzer Well No 0111-01/0111-01PB1 Date Dispatched: 21-Oct-10 Installation/Rig Nabors 245E Dispatched By: Paul Wyman Data No Of Prints No of CDs 0111-01 -Logs: 2 in MD 1 2inTVD 1 5inMD 1 5 in TVD 1 0111-01 PB1 -Logs: 2 in MD 1 2inTVD 1 5 in MD 1 5inTVD 1 0111-01/0111-01PB1 -Digital Data 1 c9f0 0(e) afr3 Received By: Please sign and return one copy to: D&M,2525 Gambell Street,Suite 400 Anchorage,Alaska 99503 pwvman@slb.com Paul Wyman Fax:907-561-8317 LWD Log Delivery V2.1,03-06-06 Page 1 of// Schwartz, Guy L (DOA) From: Brink Jason Dason.brink @enipetroleum.com] Sent: Tuesday, October 05, 2010 2:47 PM To: Schwartz, Guy L(DOA) Subject: RE: OI11-01 learnings. (Intermediate cementing) p,�0 Z/O— /06 Guy I The intermediate cement job on OI11-01 was just pumped and bumped the plugs on target. The first change was implemented and that was to stay with the old water based drilling mud to displace cement with the rig pumps. The previous failure on OP05-06 utilized OBM taken directly from trucks to displace the cement with rig pumps. Transferring OBM from trucks to the rig pumps could be a culprit for under displacing the cement plugs, so we have taken that out of the equation. The hole washout was back calculated from the last CBL run on OP05-06 and was used for this well's cement volume calculation. The CBL will be run on OI11-01 shortly and another data point for hole washout will be acquired. This data will help fine tune the Intermediate cement volumes. Lastly, we will plan 1000' cement coverage over the N sand which should help mitigate the 500'AOGCC regulation in the event of a future problem with displacement. If there are any questions, then let me know. Jason Brink Drilling Engineer ENI Alaska Office: 907-865-3321 Cell: 907-947-3790 From: Schwartz, Guy L (DOA) [mailto:guy.schwartz @alaska.gov] Sent: Monday, October 04, 2010 5:00 PM To: Brink Jason Subject: 0I11-01 learnings. (Intermediate cementing) Jason, Please do a short write-up after this well is completed and document what you learn regarding fine tuning the cement program for Intermediate casing. I will be looking at the LWD sonic and USIT fairly soon but could you document what you did different from the previous well and how it ended up...... I would think a couple of paragraphs ought to be sufficient. The commissions are very keen on making sure we capture learnings and get it documented... Thanks in advance, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) This message may contain information that is confidential, and is being sent exclusively to the Recipient. 10/5/2010 Page l of 2 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Tuesday, August 31, 2010 10:21 AM To: 'Kuck Marc' Cc: 'Brink Jason' Subject: RE: 0111-01 Injector at Oliktok Point pTD 2/0 — /66 Mark, The Commission can grant a variance to the packer setting depth (per 20 AAC 25.412 (b) ) based on TVD/MD and confining zone thickness. Your argument for setting the packer higher at 5500' and (69 deg deviation) has merit and is approved. After reviewing the well file a more detailed schematic should be included with the PTD application that specifies proposed setting depths for the completion jewelry. Please make sure future PTD applications have this included. Thanks, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Kuck Marc [mailto:marc.kuck @enipetroleum.com] Sent: Monday, August 30, 2010 5:10 PM To: Schwartz, Guy L (DOA) Subject: 0I11-01 Injector at Oliktok Point Guy, I have a question concerning our upcoming injection well 0111-01 (next well in our schedule). I would like to set my injection packer in this well further than 200 ft MD above the intermediate shoe. I believe you already have the full well package on file, so attached is the latest planned survey for reference. The approximate planned depths I would like to use are as follows: Intermediate shoe: 6315' MD, 3633' TVD, 88 deg inc. Liner Hanger/Pkr: 6115' MD, 3624' TVD, 87 deg inc. Prod Packer: 5500' MD, 3509' TVD, 69 deg inc. Top of Cement: 4800' MD, 3237' ND, 67 deg inc. This would allow me to drop the ball-and-rod for proper packer setting operations. This would place the packer approximately 125 feet ND above the intermediate shoe and still be 272 ft ND below top of cement. If you agree with this strategy, can we get approval from AOGCC to proceed with this packer setting depth? Thanks and regards, Marc D. Kuck Senior Completion Engineer ENI US Operating Co. Office: 907 865-3322 Mobile: 907 242-6942 "The charm of fishing is that it is the pursuit of what is elusive but attainable,a perpetual series of occasions for hope."—John Buchan This message may contain information that is confidential, and is being sent exclusively to the Recipient. 8/31/2010 • Page 2 of 2 If you are not the designated Recipient, you are prohibited from utilizing, copying or divulging the information contained in this message,or taking any action whatsoever on the basis of the information herein. If you have received this message by mistake, we ask you to kindly inform the Sender and to delete the message. It is understood that,with regard to messages sent by its network, the Company is not responsible for any statements made or opinions expressed, that are not strictly related to the Company's operations. II 8/31/2010 DIF /A:\ SEAN PARNELL,GOVERNOR ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 II CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 Maurizio Grandi Well Operation Project Manager ENI US Operating Co. Inc. 3800 Centerpoint Drive, Suite 300 Anchorage, AK 99503 Re: Nikaitchuq Field, Nikaitchuq Oil Pool, 0I11-01 ENI US Operating Co. Inc. Permit No: 210-106 Surface Location: 3186' FSL, 1597' FEL, SEC. 5, T13N, R9E, UM Bottomhole Location: 4937' FSL, 599' FEL, SEC. 31, T14N, R9E, UM Dear Mr. Grandi: Enclosed is the approved application for permit to drill the above referenced service well. The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and inject is contingent upon issuance of a conservation order approving a spacing exception. ENI US Operating Co. Inc. assumes the liability of any protest to the spacing exception that may occur. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Daniel T. Seamount, Jr. -tk Chair DATED this ,O day of August, 2010. cc: Department of Fish & Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) RECEIVED STATE OF ALASKA 201 ALt KA OIL AND GAS CONSERVATION COMMISSION AUG PERMIT TO DRILL DRILL Ca;CO M Co ission Ilt 20 AAC 25.005iosk i`ar �f� 1 a.Type of Work: 1 b.Proposed Well Class: Development-Oil ❑ Service- Winj el Single Zone ❑ 1 c.Sp *I wel is proposed for: Drill el Redrill ❑ Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone ❑ Coalbed Gas ❑ Gas Hydrates ❑❑ Re-entry ❑ Exploratory ❑ Service- WAG ❑ Service-Disp ❑ Shale Gas 2.Operator Name: 5. Bond: Blanket 0 Single Well ❑ 11.Well Name and Number: ENI US Operating Co Inc Bond No. RLB0008627 • 0111-01 3.Address: 6.Proposed Depth: 12.Field/Pool(s): 3800 Centerpoint Drive Suite 300,Anchorage 99503 MD: 10521' ' TVD: 3674' • Nikaitchuq 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface: 3186'FSL,1597'FEL,S5 T13N R9E UM- ADL 355024,373301,390616,391283 - Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 1709'FSL, 2875'FEL,S32 T14N R9E UM ADL 417493 9/19/2010 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 4937'FSL,599'FEL,S31 T14N R9E UM - 1280 1709' 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: 53.2 feet'15.Distance to Nearest Well Open Surface:x- 516683 • y- 6036539• Zone- 4 GL Elevation above MSL: 12 feet• to Same Pool: 1142'West to 0P12-01 16.Deviated wells: Kickoff depth: 400 feet 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 90°degrees Downhole: 1591 psig • ' Surface: _1193 psig • ' 18.Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) Driven 20" 178.89 X-65 Welded 84 36 36 120 120 pre-installed 16" 13-3/8" 68 L-80 BTC 2357 35 35 2357 • 2173 980 sx 10.7#ASL,226 sx 12.0#Deeperete • 12.25" 9-5/8" 47 L-80 BTCM 6128 33 33 6128 • 3633 368 sx 12.5#Deeperete • 8.5" 5.5" 17 L-80 DWC 4593 5928 3603 10521 - 3674 Slottled liner in open hole 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured): Effect.Depth MD(ft): Effect.Depth TVD(ft): Junk(measured): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): 20. Attachments: Property Plat el BOP Sketch 0 Drilling Program el Time v.Depth Plot ❑ Shallow Hazard Analysis❑ Diverter Sketch 0 Seabed Report ❑ Drilling Fluid Program ❑ 20 AAC 25.050 requirements el 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and correct. Contact Jason Brink @ 907-865-3321 t. Printed Name Maurizio Grandi( OA Title Well Operation Project Manager Signature PiL Phone Date R,triix3 Commission Use Only Permit to Drill API Number: /./ Permit Ap Qval See cover letter for other Number: Z(C' 7C 50- cz9 7-4.�7 '` ate: Kai_ requirements. / Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed methane, as hydrates,or gas contained in shales: 1E Other: 4-35O a,541. /36P 7 t-� Samples req'd: Yes❑ No[ Mud log req'd: Yes ❑ No [" 7- Z 5? D OS� ,4hn.la--r I C 3 f6`""^) H2S measures: Yes❑ No[ Directional svy req'd: Yes [ 'No ❑ 1 nJ�i /� p►,�cf c� {�2r ct_tlProu.X in b (lb.., •nos$ �Oh Cekn e,t `-r`A. J A.4 r( `. Dr"e-r+P-4" l ra l0e.� Z a �LZ 5.6 3 5 �ti�� S� APPROVED BY THE COMMISSION �/� O /1 U DATE: ,COMMISSIONER ORIGINAL 52-43--/c, x`'9°40 Form 10-401(Revised 7/2009) This permit is valid for 24 months from the date of approval(20 AAC 25.005(g)) Submit in Duplicate .... tot EN • lirolleum ..em RECEIVED 3800 Centerpoint Drive Suite 300 AUG 0 7.(� � Anchorage,Alaska 99503 Pone(o(907)86 - Alaska e'&Goa Co,C9mmiSSion Phone(907)865-3320 Email: Maurizio.Grandi @enipetroleum.com AilCniiNg0 August 5,2010 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage,Alaska 99501 RE: Application for Permit to Drill Injector 0111-01 Dear Commissioners, ENI US Operating Co. Inc.hereby applies for a Permit to Drill for the onshore injection well 0111-01.The I well will be drilled and completed using Nabors rig 245E. The planned spud date is 9/19/2010.. Please find attached for the review of the Commission forms 10-401 and the information required by 20 ACC 25.005 for this well bore. I If you have any questions or require further information,please contact Jason Brink at 907-865-3321. Sincerely, 4 'ttk/‘°4--/t— I Maurizio Grandi Well Operation Project Manager I rot • En Petirolleuim Application for Permit to Drill Well 0111-01 Saved:5-Aug-1 0 Application for Permit to Drill Document Injector Well 0I11-01 Table of Contents 1. Well Name 2 Requirements of 20 AAC 25.005(f) 2 2. Location Summary 2 Requirements of 20 AAC 25.005(c)(2) 2 Please see Attachment 7: Surface Platt 3 Requirements of 20 AAC 25.050(b) 3 3. Blowout Prevention Equipment Information 3 Requirements of 20 AAC 25.005(c)(3) 3 4. Drilling Hazards Information 3 Requirements of 20 AAC 25.005(c)(4) 3 5. Procedure for Conducting Formation Integrity Tests 4 Requirements of 20 AAC 25.005(c)(5) 4 6. Casing and Cementing Program 4 Requirements of 20 AAC 25.005(c)(6) 4 7. Diverter System Information 4 Requirements of 20 AAC 25.005(c)(7) 4 8. Drilling Fluid Program 5 Requirements of 20 AAC 25.005(c)(8) 5 Surface Hole Mud Program (extended bentonite) 5 Intermediate Hole Mud Program (LSND) 5 Lateral Mud Program (MI VersaPro LS Mineral Oil Base) 5 9. Abnormally Pressured Formation Information 6 Requirements of 20 AAC 25.005(c)(9) 6 10.Seismic Analysis 6 Requirements of 20 AAC 25.005(c)(10) 6 11.Seabed Condition Analysis 6 0111-01 PERMIT Document.doc Page 1 of 7 Printed:5-Aug-10 viiit Oliktok Point Nikaitchuq Field e o petroleum 0111 -01 (P4) Alaska DIR/LWD FORM DEPTH HOLE CASING MUD INFO Drilling MWD MD TVD SIZE SPECS Hazards Cement to Surface 20" Hole Angle X-65 00 20"Conductor Shoe 160' 160' N/A Welded/Driven N/A 0 GR/Res -+ Surface Csg Dir -o 13-3/8" m Base Permafrost 1,867' 1,778' > 68 lbs/ft MW(ppg) Wellbore Stability Mud Motor r L-80,BTC 8.8-9.5 Lost Circulation Hole Cleaning KOP:400' DLS: °< 1.5-3.5 deg/100' o v v m F. +ors: v Hole Angle m ¢. 44 13-3/8"Casing Point 2,357' 2,173' 16" 50°F WBM GR/RES PWD Inter.Casing Wellbore Stability 9-5/8" Lost Circulation Xceed 900 47 lbs/ft MW(ppg) Hole Cleaning L-80,BTC-M 8.8-9.5 Torque&Drag Sail Angles: 67 degrees N Hole Angle N1 "N"Sand Top 5,269' 3,411' v 11114 a NOTE: Injectors REQUIRE CBL on Intermediate Casing USIT run on tractor/E-line after setting the liner TOL 5,928' /D m �� 85 9-5/8"Casing Point 6,128' 3,633' 12-1/4" 85"F LSND GR/RES d ■ PWD Wellbore Stability Option to run sonic Lost Circulation for int.casing CBL Schrader Bluff Slotted Liner Hole Cleaning Lateral 5-1/2" Torque&Drag 17 lbs/ft MW(ppg) Xceed 675 L-80,DWC 8.8-9.0 (Geo-Steering) &hydril 521 5-1/2"Slotted Liner Hole Angle 92 TD/5-1/2"Lnr 10,521' 3,674' 8-1/2" 85"F MOBM Enil tirolIeurn Application for Permit to Drill Well OI11-01 Saved:5-Aug-10 Requirements of 20 AAC 25.005(c)(11) 6 12.Evidence of Bonding 6 Requirements of 20 AAC 25.005(c)(12) 6 13.Proposed Drilling Program 6 Requirements of 20 AAC 25.005(c)(13) 6 14.Discussion of Mud and Cuttings Disposal and Annular Disposal 7 Requirements of 20 AAC 25.005(c)(14) 7 15.Attachments 7 Attachment 1 Directional Plan 7 Attachment 2 Drilling Hazards Summary 7 Attachment 3 BOP and Diverter Configuration 7 Attachment 4 Cement Loads and CemCADE Summary 7 Attachment 5 Well Schematic 7 Attachment 6 Formation Integrity And Leak Off Test Procedure 7 Attachment 7 Surface Platt 7 1. Well Name Requirements of 20 AAC 25.005(f) Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(b). For a well with multiple well branches, each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission, Well Name: 0111-01 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (2)a plat identifying the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface, at the top of each objective formation, and at total depth, referenced to governmental section lines. (B)the coordinates of the proposed location of the well at the surface,referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C)the proposed depth of the well at the top of each objective formation and at total depth; Location at Surface 3186'FSL, 1597' FEL, S5 T13N R9E UM ASP Zone 4 NAD 27 Coordinates RKB Elevation 53.2'AMSL Northings 6036539.39' Eastings: 516682.79' Pad Elevation 12'AMSL Location at Top of Productive Interval 1709' FSL, 2875' FEL, S32 T14N R9E UM ("OA"Sand) 0111-01 PERMIT Document.doc Page 2 of 7 Printed:5-Aug-10 Tritix• Emil Petirolleurn Application for Permit to Drill Well 0111-01 Saved:5-Aug-10 ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 5978' Northings: 6040337.51' Eastings:515384.95' Total Vertical Depth, RKB: 3616' Total Vertical Depth, SS:: 3564' Location at Total Depth 4937' FSL, 599'FEL, S31 T14N R9E UM ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 10521' • Northings: 6043561.00' Eastings: 512364.00' Total Vertical Depth, RKB: 3673' Total Vertical Depth, SS:: 3621' Please see Attachment 7: Surface Platt and (D)other information required by 20 AAC 25.050(b); Requirements of 20 AA C 25.050(b) If a well is to be intentionally deviated, the application for a Permit to Drill(Form 10-401)must (1)include a plat,drawn to a suitable scale,showing the path of the proposed wellbore, including all adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment 1: Directional Plan and (2)for all wells within 200 feet of the proposed wellbore (A)list the names of the operators of those wells, to the extent that those names are known or discoverable in public records, and show that each named operator has been furnished a copy of the application by certified mail;or (B)state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (3)a diagram and description of the blowout prevention equipment(BOPE)as required by 20 AAC 25.035, 20 AAC 25.036, or 20 MC 25.037,as applicable; Please see Attachment 3: BOP and Diverter Configuration 4. Drilling Hazards Information Requirements of 20 AAC 25.005(c)(4) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (4)information on drilling hazards,including (A)the maximum downhole pressure that may be encountered, criteria used to determine it, and maximum potential surface pressure based on a methane gradient; The expected reservoir pressure in the Schrader Bluff sand is 0.44 psi/ft, or 8.5 ppg EMW (equivalent mud weight). The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient(0.11), and the planned vertical depth of the OA sand formation is 1193 psi: MPSP = (3616 ft TVD)(0.44 - 0.11 psi/ft) = 1193 psi (B)data on potential gas zones; 0111-01 PERMIT Document.doc Page 3 of 7 Printed:5-Aug-10 ...... los, Enii • _eat Application for Permit to Drill Well 0111-01 Saved:5-Aug-10 The well bore is not expected to penetrate any gas zones. and . (C)data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation zones,and zones that have a propensity for differential sticking; Please see Attachment 2: Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005(c)(5) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (5)a description of the procedure for conducting formation integrity tests,as required under 20 AAC 25.0300; Please see Attachment 6: Formation Integrity And Leak Off Test Procedure 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (6)a complete proposed casing and cementing program as required by 20 AAC 25.030, and a description of any slotted liner,pre- perforated liner, or screen to be installed; Casing and Cementing Program See also Attachment 4: Cement Summary Hole Top Btm Csg/Tbg Size Weight Length MD/TVD MD/TVD OD(in) (in) (lb/ft) Grade Connection (ft) (ft) (ft) Cement Program 20 178.89 X-65 Welded 120 36/ 36 1207 120' Cemented to surface Cemented to Surface with 980 sx 10.7#ASLite Lead Yield 2.33 cu. Ft./sk, 13-3/8 16 68 L-80 BTC 2357' 35/ 35 2357'/ 2173' 226 sx 12.0#DeepCRETE Tail Yield 1.58 cu.ft./sk Cement Top planned @ 4769'MD Cemented w/368 sx 12.5# 9-5/8 12-1/4 47 L-80 BTCM 6128' 33/ 33 6128'/ 3633' DeepCRETE Yield 1.54 cu.ft./sk 8-1/2"OA 5-1/2 Sand 17 L-80 DWC 4593' 5928'/ 3603' 105217 3674' Slotted Liner-no cement Lateral 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (7)a diagram and description of the diverter system as required by 20 MC 25.035, unless this requirement is waived by the commission under 20 MC 25.035(h)(2); Please see Attachment 3: BOP and Diverter Configuration OI11-01 PERMIT Document.doc Page 4 of 7 Printed:5-Aug-10 _} • Enil tiroHeum Application for Permit to Drill Well 0111-01 Saved:5-Aug-10 A 21-1/4", 2000 psi diverter with a 16"diameter diverter line and valve has been the diverter system used for drilling the surface hole. The AOGCC has waived the mandatory use of diverter on Surface hole. . 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (8)a drilling fluid program,including a diagram and description of the drilling fluid system,as required by 20 AAC 25.033; Drilling will be done with muds having the following properties over the listed intervals: Surface Hole Mud Program(extended bentonite) Spud to Base of Permafrost Base of Permafrost to Casing Point Initial Value Final Value Initial Value Final Value Density(ppg) 8.8 9.2 9.2 9.5 Funnel Viscosity 150 250 200 300 (seconds) Yield Point 50 70 30 50 (lb/100 sf) Plastic Viscostiy 30 55 15 20 (CP) pH 9.0 9.5 9.0 9.5 API Filtrate NC 8.0 8.0 8.0 (cc/30 min)) MBT <18.0 Intermediate Hole Mud Program(LSND) Lateral Mud Program (Mineral Oil Base) 13-3/8"Csg Shoe to 9-5/8"Csg Point Value Value Density(ppg) 9.0-9.3 • Density(ppg) 8.8 - 9.5 • Plastic Viscostiy Funnel Viscosity (CP) 15-25 (seconds) 45 - 60 Yield Point Plastic Viscostiy (lb/100 sf) 15-20 (CP) 12 - 18 HTHP Fluid loss Yield Point 18.24 (ml/30 min @ <5.0 (lb/100 sf) 200psi& 100°F API Filtrate Oil/Water Ratio 75/25 (cc/30 min)) 4 - 6 Electrical >600 Chlorides(mg/I) <500 _ Stability pH 9.0- 10.0 Drilling fluid practices will be in accordance with appropriate regulations stated in 20 MC 25.033. 0/11-01 PERMIT Document.doc Page 5 of 7 Printed:5-Aug-10 ..... irmiki Eni Petirolleurn Application for Permit to Drill Well 0111-01 Saved:5-Aug-10 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005(c)(9) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (9)for an exploratory or stratigraphic test well,a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 AAC 25.033(f) Not applicable: Application is not for an exploratory or stratigraphic test well. 10.Seismic Analysis Requirements of 20 AAC 25.005(c)(10) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (10)for an exploratory or stratigraphic test well,a seismic refraction or reflection analysis as required by 20 MC 25.061(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 11.Seabed Condition Analysis Requirements of 20 AAC 25.005(c)(11) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (11)for a well drilled from an offshore platform,mobile bottom-founded structure,jack-up rig, or floating drilling vessel, an analysis of seabed conditions as required by 20 MC 25.061(6); Not applicable: Application is not for an offshore well. 12.Evidence of Bonding Requirements of 20 AAC 25.005(c)(12) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (12)evidence showing that the requirements of 20 MC 25.025{Bonding}have been met; Evidence of bonding for ENI is on file with the Commission. 13.Proposed Drilling Program Requirements of 20 AAC 25.005(c)(13) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: 1 The proposed drilling program is listed below. Please refer also to Attachment 5, Well Schematic. 1. Move in/ rig up Nabors 245E. 2. Spud and directionally drill 16" hole to casing point as per directional plan. Run Gyro and MWD tools as . required for directional monitoring. 3. Run and cement 13-3/8", 68#, L80, BTC casing to surface. Pump cement and displace with mud, land casing hanger and bump plug. 4. Install and test wellhead to 5000 PSI. 5. Nipple up 13-5/8"5K BOP and test to 3500 PSI. Notify AOGCC 24 hrs before test. 6. Pressure test casing to 2500 psi per AOGCC regulations. Record results. 7. PU 12-1/4" bit and directional drilling assembly with MWD, LWD and PWD. 8. Drill out cement and between 20'and 50' of new hole. Perform formation integrity test, recording results. 0111-01 PERMIT Document.doc Page 6 of 7 Printed:5-Aug-10 Eni Petirolleum _ern Application for Permit to Drill Well OI11-01 Saved:5-Aug-10 9. Directionally drill to 9-5/8"casing point per directional plan. 10. Install 9-5/8"casing rams in the BOP and test to 3500 PSI. • 11. Run and cement 9-5/8", 47# L80, BTC Mod casing. Pump cement and displace with mud, land casing • hanger and bump plug. 12. Install 9-5/8" packoff and test to 5000 psi. • 13. Flush 13-3/8"x 9-5/8"annulus with diesel freeze protect. 14. Pressure test casing to 3000 psi per AOGCC regulations. Record results. • 15. PU 8-1/2"bit and directional drilling assembly including MWD, LWD, PWD and rotary steerable tool. RIH, clean out cement to top of float equipment. 16. Drill out cement and between 20'and 50' of new hole. Perform formation integrity test, recording results. f J C&L / , 4 C■se ± 17. Directionally drill 8-1/2" hole to TD as per directional plan. 0 18. PU and run 5-1/2"slotted liner to TD. 19. Land liner, set liner hanger inside the 9-5/8"intermediate casing. POOH laying down DP as required. 20. PU Injection packer and 4-1/2"tubing as required and RIH to depth. Set Injection Packer and Land tubing. Set BPV. 21. Nipple down BOP, nipple up tree and test. Pull BPV. 22. Test IA to 2500 PSI and chart for 30 minutes. 23. Freeze protect well with diesel to the base of the permafrost. 24. Set BPV and Move rig off. - 14.Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005(c)(14) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (14)a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 MC 25.080 for an annular disposal operation in the well.; Waste fluids generated during the drilling process will be disposed of by injection down an Oliktok Point Class I disposal well or by hauling the fluids to the Prudhoe Bay Grind and Inject Facility. All cuttings generated will be disposed of either down an Oliktok Point Class I grind and inject disposal well or hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well. 15.Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 BOP and Diverter Configuration Attachment 4 Cement Loads and CemCADE Summary Attachment 5 Well Schematic Attachment 6 Formation Integrity And Leak Off Test Procedure Attachment 7 Surface Platt 0111-01 PERMIT Document.doc Page 7 of 7 Printed:5-Aug-10 M a O 9 7 r r Q r m N n r rn r g Q O D N rn M O rn t o O rn MOD Q N N n W ,':-.:2,742,% M M O toi m NN OiN N .-60SON QQ NtOa mODNMQ M•'MM.- OOtOry m 4" fV N fV O 1� M r cj O pj try co V �N Oi tftppV�: yNy OG Q7�N fV I■C lV O nj N�N � 0 tO N N r b N g g g g tN0 t o MILLI NNN cry c O NNN rny p d V a v EMI N N N rn co W g cNO E c0 cNO tp N I to to co to tp tD N N N N N R N t0 NN N tp cONNN NtoNN a. 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W 149 51 46 543 EasSng. 516682 7981U Scale Fad 099990032 Plan 0111-01(P4) Spry Date:July 29,2010 -4000 -3000 -2000 -1000 0 011141(P4) TD 7000 7000 End Cry End Cry 0111-01 Tgt7 0111-01 Tgt 8 Cry 2/100 Cry 2/100 End Cry 0111-01 Tgt 5 6000 End Cry 6000 6000 0111-01 Tgt .•. ..�. . Cry 2/100 End Cry 0111-01 Tgt 4 Cry 2/100 • • End Cry End Cry 5000 D1T111TTgT3 0111-0itgt2 5000 Cry 2.5/100 A A A Z Cry 9.5/100 45/0°Cog 4000 ..End.Gty 4000 Cry 2.5/100 0 End Cry C 11 Cry 3/100 0) End Cry Cry 4/100 3000 3000 to V V V Fault I 2000 2000 End Cry 1000 1000 13-3/8"Csg Cr 3.5/100 Gyro Pt Cry 0.5/100 RTE 0 Crx3.5/100 0 Bld 2.25/100 KOP Bid 1.5/100 -4000 -3000 -2000 -1000 0 <<< W Scale=1(in):1000(ft) E >>> Schlumberger 0111-01 (P4) Anti-Collision Summary Report Analysis Date-24hr Time: July 29,2010-10:36 Analysis Method: Normal Plane Client: ENI Reference Trajectory: 0111-01(P4)(Def Plan) Field: Nikaitchuq Depth Interval: Every 10.00 Measured Depth(ft) Structure: Oliktok Point Rule Set: O&M AntiCollison Standard Slot: OP11 Min Pts: All local minima indicated. Well: 0111-01 Borehole: OP11-101 Offset Trajectories Summary Offset Selection Criteria Wellhead distance scan: Restricted within 40000 ft Selection filters: Definitive Surveys-Definitive Plans-Definitive surveys exclude definitive plans -All Non-Def Surveys when no Def-Survey is set in a borehole-All Non-Def Plans when no Def-Plan is set in a borehole Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft)I EOU(ft)_ Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major OP10-P09(P1)(Def Plan) Warning Alert 8.00 6.08 4.76 N/A 0.00 0.00 Surface 8.00 4.86 4.25 4.98 240.00 240.00 OSF<5.00 MinPt-O-ADP 1 8.00 4.79 4.14 4.7t 250.00 250.00 MinPt-CICt 8.49 4.141 2.92 2.70 369.98 369.98 MinPt-O-EOU 9.06 4.26 2.82 2.48 399.95 399.95 MinPt-O-ADP 9.99 4.71 3.03 2.401 429.94 429.94 MinPt-O-SF 39.92 30.31 26.47 4.94 791.30 790.12 OSF>5.00 Exit Alert 789.14 764.02 752.34r- 33.701 3936.52 2895.11 MinPt-O-SF MME,6 715.36 678.59 10.73 7707.74 3667.93 Min171-CtCt 794.7:MOM. 669.16 9.59 7837.76 3670.20 MinPt-O-EOU 799.75 711.4•. 668.1 9.21 7892.16 3670.86 MinPt-O-ADP 959.54 835.44 ---774.1:1113 8445.79 3671.89 MinPt-O-SF 1427.18 1269.51 1191.4:� 9562.84 3684.15 MinPt-O-SF INEE23E=mg 1004.6 I VI 10521.35 3673.05 MinPts OP09-503(P1)(Def Plan) Warning Alert 15.99 14.07 12.75 N/A 0.00 0.00 Surface I 15.991 12.42 11.60 8.53 300.00 300.00 MinPt-CtCt 1 16.341 12.13 10.99 6.30 379.99 379.99 MinPt-O-EOU 16.68 12.19 10.901 5.74 409.99 409.99 MinPt-O-ADP 18.42 13.18 11.52 4.96 480.02 480.02 OSF<5.00 MinPt-O-ADP 20.69 14.86 12.90 530.06 530.03 MinPt-0-SF 25.99 19.25 16.83 4.98 610.19 610.05 OSF>5.00 Exit Alert • 109.72 88.87 79.40j1 5.63 1199.07 1184.85 MinPt-O-SF 1026.76 981.02 12.22 6552.58 3662.68 MinPt-CICt 1121.5 MORI 977.86 11.82 6633.93 3666.68 MinPt-O-EOU 1123.41 1025.59 mug 11.66 6670.38 3668.25 MinPt-O-ADP 1213.91 1098.50 1041.60 mom, 7102.80 3676.31 MinPt-O-SF 2828.55 2677.01 2602.0 gm= 9071.66 3684.40 MinPt-O-SF 2997.23 2839.25 2761.0.main 9558.29 3684.15 MinPt-O-SF "S.:,I10611110EM M., 10521.35 3673.05 MinPts OP12-01 current(Non-Def Survey) Warning Alert 7.84 6.21 4.60 16.11 127.62 127.62 MinPts 7.94 6.08 4.69 10.63 167.62 167.62 MinPt-O-EOU 10.52 7.41 6.47 4.94 317.52 317.52 OSF<5.00 MinPt-O-ADP 60.61 34.34• 2.37 1127.69 1117.66 MinPt-O-ADP 68.32 38.07 23.55® 1194.80 1180.86 MinPt-O-SF 213.67 169.94 148.68 5.00 2283.19 2118.56 OSF>5.00 Exit Alert 308.13 252.75 225. ° .I, 3077.71 2563.32 MinPt-0-SF 966.85 866.79 817.25 9.75 5376.19 3450.61 TD OP08-04PB1(Del Survey) Warning Alert I 23.80f1 225711 20.551 647859.30 0.00 0.00 MinPts • 2416 2192 20.91 22.70 188.89 188.89 MinPt-O-EOU 75.63 59.53 52.08 5.00 933.44 930.21 OSF<5.00 MinPt-O-ADP 107.32 78.68 64.97 liEg 1208.41 1193.57 MinPt-O-SF 158.91 125.89 110.00 4.96 1481.65 1439.94 OSF>5.00 Exit Alert 1141.53 1050.68 1005.7 5706.86 3557.36 MinPt-O-SF 1208.83 1112.89 1065.41® 5988.91 3617.85 MinPt-O-SF 1600.81 1490.01 1435.11 MEE 7022.89 3676.31 MinPt-O-SF 1602.82 1491.89 1436.92 Mtn 7034.69 3676.35 MinPt-O-SF 1627.30 1514.89 1459.1 14.60 7164.35 3675.77 MinPt-O-SF jjjjjjj t1 468.0: 1409.6 ® 7677.79 3667.32 MinPts OP08-04(Del Survey) Wanting Alert I 23.80 22.57 20.551 71266.70 8.90 8.90 MinPts 24.16 21.92 20.91 22.70 188.89 188.89 MinPt-O-EOU 75.63 59.53 52.08 5.00 933.44 930.21 OSF<5.00 MinPt-O-ADP 107.32 78.68 64.971 3.871 1208.41 1193.57 MinPt-O-SF 158.91 125.89 110.00 4.96 1481.65 1439.94 OSF>5.00 Exit Alen 1141.53 1050.69 1005.751_ 12.69 5706.86 3557.36 MinPt-O-SF 1208.83 1112.89 1065_421 12.721 5988.91 3617.85 MinPt-O-SF 1600.81 1490.02 1435.121 14.571 7022.89 3676.31 MinPt-O-SF 1602.82 1491.90 1436.92 14.57 7034.69 3676.35 MinPt-O-SF 1624.56 1512.35 1456.74 14.60 7146.43 3675.98 MinPt-O-SF Drilling Office 2009.1.745.0 Nikaitchuq\Oliktok Point\0111-01\OP11-101\0111-01(P4) 7/29/2010 10:36 AM Page 1 of 8 Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft EOU(ft Dev.(ft Fact. MD(ft) I TVD(ft) Alert I Minor I Major 1, 1298.221 1142.1 1064.691 8.34 9792.46 3685.33 MinPts OP13-103(P1)(Def Plan) Warning Alert 31.98 30.07 28.74 N/A 0.00 0.00 Surface 1 31.981 27.70 26.52 12.72 400.00 400.00 MinPt-CtCt 32.12 27.591 26.28 11.56 439.95 439.95 MinP1-0-EOU 32.19 27.61 26.271 11.34 449.94 449.94 MinPt-O-ADP 71.26 55.44 48.48 4.98 986.00 981.50 OSF<5.00 MinPt-O-ADP 107.55 78.80 65.39 1200.37 1186.07 MinPt-O-SF 156.93 123.70 108.04 4.95 1422.07 1387.21 OSF>5.00 Exit Alert 2399.21 2300.09 2251.33 24.5 6149.48 3634.37 MinPt-O-SF 2463.04 2343.35 2284.301 20.841 7871.11 3670.62 MinPt-O-SF 11 1999.7911 1828.7911 1744.0811 11.801 1052135 3673.05 MinPts OP26-DSPO2(Def Survey) Warning Alert 1=711-3 -91-3= N/A 0.00 0.00 MinPts 270.01 241.94 228.87' 10.26 1427.09 1391.65 MinP1-0-SF 153.09 120.88 105.68 4.98 2440.76 2230.82 OSF<5.00 MinP1-0-ADP 118.21 88.31 74.281 4.151 2664.71 2370.99 MinPI-0-SF 113.24 85.241 72.15) 4.26 2734.48 2409.65 MinPt-O-ADP 112.671 85.121 7225 4.31 2748.84 2417.29 MinPt-O-EOU 1 112.20 85.58 73.18 4.45 2776.84 2431.90 MinPt-CtCt 113.79 89.22 77.83 402 2832.65 2459.77 OSF>5.00 Exit Alert 2984.54 2948.37 2931.0.1 86.301 6330.43 3648.30 MinP1-0-SF OP14-108(P1)(Def Plan) Warning Alert 39.98 38.06 36.73 N/A 0.00 0.00 Surface 1 39.98 35.70 34.52 16.11 400.00 400.00 MinPt-CtCt 40.11 35.58 34.28 14.63 439.94 439.94 MinPt-O-EOU 40.18 35.60 34.261 14.35 449.93 449.93 MinPt-O-ADP 94.27 73.83 64.56 4.98 1073.47 1065.96 OSF<5.00 MinPt-O-ADP 122.07 93.47 80.13 MIME 1198.63 1184.44 MinPt-O-SF 153.47 120.75 105.35 4.92 4.92 1312.38 1289.17 OSF>5.00 Exit Alert 3823.72 3715.06 3661.5 35.701 6148.21 3634.13 MinPI-0-SF 3676.47 354860 3485.4 29.101 7884.60 3670.78 MinP1-0-SF 3791.6011 3609 0811 3518.63( 20.951 10521.35 3673.05 MinPts OP06-105(P3)(Def Plan) Warning Alert 47.99 46.07 44.74 N/A 0.00 0.00 Surface 1 47.991 44.06 43.06 22.94 350.00 350.00 MinPt-CtCt 48.2'71 43.861 42.61 18.89 410.02 410.02 MinPt-O-EOU 48.51 43.92 42.591 17.45 440.07 440.07 MinPt-O-ADP 110.27 86.65 75.81 4.99 1118.69 1109.12 OSF<5.00 MinPt-O-ADP 132.36 103.56 90.1211111111111111111 1194.91 1180.97 MinPt-O-SF 141.89 111.92 97.90 4.99 1222.95 1207.09 OSF>5.00 Exit Alert 5901.69 5784.88 5727.2.MlaRf 6764.32 3671.67 MinPt-O-SF 5910.42 5793.44 5735.7'® 6769,43 3871.83 MinP1-0-SF 7444.04 7306.97 7239.2 54.94 7438.56 38688.06 MinPt-O-SF 7716.05 7576.45 7507.46 55.91 7534.61 3665.84 TD OP19-ENI#1(Pt)(Non-Def Plan) Pass 88.021 8361 82.66 37.53 390.20 39020 MinPt-CtCt MEC 74.08 71.06 13.25 735.60 734.89 MinPt-CtCt 82.4 MI= 70.27 11.78 774.07 773.05 MinPt-O-EOU 82.70 73.74®' 11.47 783.63 782.53 MinPt-O-ADP 89.59 78.87 74.46 1 i 878.04 875.78 MinPt-O-SF 7215.87 7156.21 7127.27 124.61 5376.44 3450.70 TD OP20-ENI#9(P1)(Non-Def Plan) Pass 1 96.04/ 91.83 90.68 41.03 390.20 390.20 MinPf-CtCt ly 94.06 87.63 85.38 20.45 657.49 657.19 MinPI-C1C1 94.47 87.27 84.63 17.52 706.03 705.51 MinP1-0-EOU 94.93 87.35 84.51 16.41 725.32 724.67 MinPt-O-ADP 111.79 100.90 96.41 12.241 894.50 891.98 MinPt-O-SF 7513.73 7488.64 7476.97 321.90 2993.10 2530.54 TD Oliktok Point I-2PB1(Def Survey) Pass 80.50 79.39 77.26 N/A 0.00 0.00 Surface t t 79. • l00 N/A 40.00 40.00 MinPts MIMI 56.85 53.22 8.84 79923 797.96 MinPt-CtCt 65. :MOM=EU 846 82924 827.65 MinPts 66.93 57.77 53.7 1 �8 889.35 886.91 MinPt-O-SF 67.95 58.67 54.541 8, 909.50 906.72 MinPt-O-SF 124.45 102.70 92.38 mum 1229.47 1213.14 MinP1-0-SF 2583.03 1017,15 434.0 3014.98 3432.56 MinPt-O-SF 2583.03 2483.38 38 2434.04� 5327.71 1 3432.56 Min%-0-SF 2785.77 267877 2625.7 M11311/ 5618,48 3530.25 MinPt-O-SF 3013.15 2899.59 2843.30 26.76 5883.65 3599.97 TD Oliktok Point 1-2(Del Survey) Pass 80.5_-0-/1 79.39 77.26 N/A 0.00 0.00 Surface I 80. 79. .lam N/A 40.00 40.00 MinPts 65.21 56.85 53.22 8.84 79923 797.96 MinPt-CtCt 65. 56.671 52.87 8.46 829.24 827.65 MinPts 66.93 57.77 53.751 8.181 889.35 886.91 MinPt-O-SF 67.95 58.67 54.581 8.181 909.50 906.72 MinPt-O-SF Drilling Office 2009.1.745.0 Nikaitchuq\Oliktok Point\0111-01\OP11-101\0111-01(P4) 7/29/2010 10:36 AM Page 2 of 8 Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft)I EOU(ft) Des.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major 124.45 102.70 92.38 5.98 1229.47 1213.14 MinPt-O-SF 1061.93 1017.15 995.25( 24.231 3014.98 2539.09 MinPt-O-SF 2493.08 2395.56 2347.291 25.821 5235.59 3396.98 MinPt-O-SF 3238.7311 3096.7811 3026.2911 22.97 7634.31 3666.45 MinPts 1 3242.8611 3098.40 3026.65 22.59 7898.75 3670.93 MinPt-CICY 3242.86 3098.38 3026.63 22.59 7904.36 3670.99 MinPt-O-EOU 3243.04 309842 3026.60 22.57 7986.66 3671.62 MinPt-O-ADP 1 2721.401 2528.61 2432.70® 10521.35 3673.05 MinPts Oliktok Point I-2Pa2(Del Survey) Pass 80.50 79.52 77.26 N/A 0.00 0.00 Surface 60.501 79.391 J00 N/A 40.00 40.00 MinPts mon 56.87 53.25 8.87 799.23 797.96 MinPt-CtCt 65.38 56.69 8.49 829.24 827.65 MinPts 66.93 57.79 53.7:�. y 889.35 886.91 MinPt-O-SF 67.95 58.69 54.61 909.50 906.72 MinPt-O-SF 124.45 102.71 92.39 1229.47 1213.14 MinPt-O-SF 1061.93 1017.15 9952.iMINIZIE 3014.98 2539.09 MinPt-O-SF 2493.08 2395.56 2347.2•=gm 5235.59 3396.98 MinPt-O-SF 3238.7 3096.78 3026.30 22.97 7634.31 3866.45 MinPts ' 3242.86 3098.40 3026.66 22.59 7898.75 3670.93 MinPt-CtCt 3242.86 3098.39 3026.64 22.59 7904.36 3670.99 MinPt-O-EOU 3243.04 3098.42 3026.60 22.57 7986.66 3671.62 MinPt-O-ADP Man 2525.08 2429 24 IMO 10521.35 3673.05 MinPts OP22-ENI#1(P2)(Def Plan) Pass 111.98 110.06 108.73 N/A 0.00 0.00 Surface 104.32 95.67 92.30 15.20 772.47 771.46 MinPt-CICI 104.89 95.111 91.18 13.10 820.03 818.54 MinPt-O-EOU 105.19 95.19 91.141 12.77 829.47 827.87 MinPt-O-ADP 115.74 103.53 98.39 11.061 949.17 945.60 MinPt-O-SF 7219.37 7159.47 7130.40 124.15 5376.71 3450,80 TD OP05-06(P8)(Def Plan) Pass 56.04 54.82 52.79 N/A 0.00 0.00 Surface 52.62 51.52 24.93 350.00 350.00 MinPt-CICt 56. 4 MEG 51.27 22.22 390.00 390.00 MinPt-O-EOU 56.30 52.52 MMIEE 21.55 400.00 400.00 MinPt-O-ADP 97.81 89.63 86.1 IMMEi 783.29 782.18 MinPt-O-SF 120.69 110.68 106.28 Emma 857.63 855.67 MinPt-O-SF 148.74 136.73 131.3 MIZE 929.35 926.20 MinPt-O-SF 6192.71 6146.08 6123.2 MMI 3114.25 2577.44 MinPt-O-SF 6913.25 6806.29 6753.30 m3E1 6372.31 3651.39 MinPt-O-SF 6994.58 6884.27 6829.61 msni 6488.23 3659.03 MinPt-O-SF 7091.65 6978.36 6922.21 M3IIMI 6568.01 3883.49 MinPt-O-SF 7369.05 7252.50 7194.71 mow 6734.15 3670.67 MinPt-O-SF 7559.81 743924 7379.4 MEM 6826.19 3673.42 MinPt-O-SF 8086.47 795821 7894.5 I_ l 7035.67 3676.36 MinPt-O-SF 8270.65 8140.04 8075.2 63.80 7098.19 3676.33 MinPt-O-SF 8281.88 8151.10 8086.24 63.80 7101.87 3676.31 MinPt-O-SF 9262.92 9120.87 9050. 'M211:2 7443.04 3667.90 MinPt-O-SF 9299.54 9157.07 9086.32 65.72 7454.16 3667.51 TD OPO4-07(Def Survey) Pass milEj 60.62 59.95 45.73 278.84 278.84 MinPt-CtCt • 63.31 mlim 59.78 40.33 318.84 318.84 MinPt-O-EOU 63.44 60.58 marz 37.99 338.84 338.84 MinPt-O-ADP 144.25 117.75 105.11 Imo 1202.67 1188.21 MinPt-O-SF 1483.50 1401.54 1381.0 5429.76 3468.81 MinPt-O-SF 1529.42 1444.81 1402."IIIMEIE 5562.65 3512.07 MinPt-O-SF 1686.08 1587.97 1539.44 ENNEEI 6321.93 3647.65 MinPt-O-SF 5403.94 5276.67 5213.53 42.78 9038.25 3684.29 TD • OPO4-07P81(Def Survey) Pass 63.201 60.62 59.95 45.73 278.84 278.64 MinPt-CtCt 63.31 60.551 59.78 40.33 318.84 318.84 MinPt-O-EOU 63.44 60.58 59.76 37.99 338.84 338.84 MinPt-O-ADP 144.25 117.75 105.11 5.66 1202.67 1188.21 MinPt-O-SF 1483.50 1401.55 1361.071 18.311 5429.76 3468.81 MinPt-O-SF 1529.42 1444.82 1403211 18.281 5562.65 3512.07 MinPt-O-SF 1686.08 1587.98 1539.421 17.351 6321.93 3647.65 MinPt-O-SF 4138.61 4023.53 3966.48 36.26 8199.88 3671.88 TD OP07-104(P2)(Def Plan) Pass 31.99 30.08 28.75 N/A 0.00 0.00 Surface 31.991 27.71 26.53 12.71 400.00 400.00 MinPt-CtCt 32.09 27.60 26.32 11.76 430.03 430.03 MinPI-O-EOU 32.16 27.61 26.30 11.50 440.04 440.04 MinPt-O-ADP 158.39 130.76 11720 6 08 1198.65 1184.46 MinPt-O-SF 2739.95 2635.15 2583.561 26.541 6371.16 3651.31 MinPt-O-SF 5476.86 5349.30 5286.32 43.47 8023.34 3671.77 TD OP21-ENI#10(P9)(Non-Def Plan) . Pass 103.99 102.08 100.75 N/A 0.00 0.00 Surface 1, 103.95 99.79 98.66 45.43 419.90 419.90 MinPt-CICt 104.07 99.65 98.39 40.75 479.54 479.53 MinPt-O-EOU 104.251 99.66 98.32 38.23 509.27 509.25 MinPt-O-EOU Drilling Office 2009.1.745.0 Nikaitchuq\Oliktok Point\0111-01\OP11-101\0111-01(P4) 7/29/2010 10:36 AM Page 3 of 8 • Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft)I EOU(ft) Dev.(ft)... Fact. MD(ft) I TVD(ft) Alert I Minor I Major 104.44 99.69 98.28 3620 529.01 528.99 MinPt-O-ADP 164.87 150.00 143.52 12.581 1068.85 1061.53 MinPt-O-SF 6303.21 6280.62 6270.20 302.50 3955.35 2902.38 TI) OP15-P08(P2)(Def Plan) Pass 48.02 4660 44.78 N/A 0.00 0.00 Surface man 44.60 43.50 21.31 350.00 350.00 MinPt-CICt 48.09=MEE 43.31 19.76 380.00 380.00 MinPt-O-EOU 48.14 44.50=CM 19.40 390.00 390.00 MinPt-O-ADP 179.86 152.39 139.27 6.81 1196.90 1182.82 MinPt-O-SF 3753.66 3651.79 3601.3, 5430.97 3469.20 MinPt-O-SF 4309.27 4192.07 4133.9 MiEri 6025.90 3622.79 MinPt-O-SF 4074.31 3930.60 3859.2 MEE 8025.16 3671.78 MinPt-O-SF 4317.22 4125.1.1 4029.67 22.59 10179.71 3684.78 MinPt-O-ADP 4353.63 4152.20 4051.98 21.72 10521.35 3673.05 TD II 4247.861 4113.3411 4046.5811 31.80i1 6842.53 3673.81 MinPts OP16-P03(P2)(Def Plan) Pass 56.01 54.09 52.76 N/A 0.00 0.00 Surface man 52.44 51.62 32.83 300.00 300.00 MinPt-CtCt 56.09 gmagi 51.42 29.55 330.00 330.00 MinPt-O-EOU 56.23 52.36 Marc 27.84 350.00 350.00 MinPt-O-ADP 184.74 155.50 141.84 6.69 1203.08 1188.59 MinPt-O-SF 3940.73 3847.97 3802.4 5324.02 3431.14 MinPt-O-SF 4264.06 4163.93 4114.7 miagE 5625.02 3532.38 MinPt-O-SF 4357.83 4226.00 4160.8:1111111BEE 8041.35 3671.82 MinPt-O-SF 4713.61 4535. •MaMit3 26.67 10175.34 3684.93 MinPt-O-ADP 4807.06 4620.00 4527.28=En 10521.35 3673.05 MinPt-O-SF OP23-W W02(Def Survey) Pass 118.93 116.521 .01 99.41 267.98 267.98 MinPts 118.9 116.22 115.47 78.55 329.00 329.00 MinPt-CICt 119.00 115.85 114.89 61.07 414.48 414.48 MinPt-CtCt 119.0.MEM 114.83 58.86 428.88 428.88 MinPt-O-EOU 115.78 114.71 54.94 458.75 458.75 MinPt-CtCt 119.50=11EM 114.07 42.18 568.02 567.95 MinPt-O-EOU 120.2•_ 113.71 33.38 637.26 637.04 MinPt-O-EOU 121.5.® 113.42 2622 706.18 705.66 MinPt-O-EOU 122.58 115.98=HE 22.56 745.37 744.59 MinPt-O-ADP 175.87 155.86 146.47 "ICI 119527 1181.30 MinPt-O-SF 58029 560.88 551.7'.miggs 2941.95 2509.51 MinPt-O-SF 631.76 610.79 600.8 5L5/ 3031.69 2545.54 MinPt-O-SF 723.37 699.50 688.1.miss 3222.17 2619.13 MinPt-O-SF 851.83 824.28 811.04 min 3476.40 2717.35 MinPt-O-SF 972.20 941.04 925.04 mom 3731.84 2816.03 MinPt-O-SF 1158.83 1121.86 11036 MEM 4145.52 2975.85 MinPt-O-SF 1200.40 1162.13 1143.04® 4238.15 3011.63 MinPt-O-SF 1339.20 1296.96 1276.3 mffigo 4544.57 3130.01 MinPt-0-SF 1718.34 1664.73 1638.42 MOM 5324.22 3431.21 MinPt-O-SF 2507.08 2445.90 2415.81 jjjjjjjjjjjj 0 6174.01 3636.22 MinPt-O-SF 6437.14 6384.48 6358.64 124.56 7147.97 367596 TD OP03-P05PB1(Def Survey) Pass � 69.901j00 827.17 68.00 68.00 MinPts l�s iJ 69.09 68.59 7021 243.37 243.37 MinPt-CtCt 72.15 MEM 68.30 54.43 299.00 299.00 MinPt-O-EOU 72.29 68.97 68.26 49.89 319.00 319.00 MinPt-O-ADP 187.13 159.85 147.18 1194.18 1180.28 MinPt-O-SF 2903.45 2863.29 2844.08 2904.94 2493.40 MinPt-O-SF 3450.02�'MMEM0 3948.00 2899.54 MinPts OP03-P05(Def Survey) Pass 69.•1 68 6.1 827.17 68.00 68.00 MinPts ®i 69.09 68.59 7021 243.37 243.37 MinPt-CtCt 72.15 68.94 68.30 54.43 299.00 299.00 MinPt-O-EOU 72.29 6897 68.26 49.89 319.00 319.00 MinPt-O-ADP 187.13 159.85 147.18 1194.18 1180.28 MinPt-O-SF 2903.45 2863.29 2844.0:1 as 2904.94 2493.40 MinPt-O-SF 4056.31 3956.85 39079 6347.71 3649.60 MinPt-O-SF 4133.31 4032.11 3982.31 MMILE 6435.94 3655.75 MinPt-O-SF 5734.28 5620.04 5563.72.®1' 7441.92 3667.94 MinPt-0-SF 5912.14 5774.1•! 5705.81® 7516.67 3666.04 MinPts OP03-P05PB2(Def Survey) Pass MIE/ 69.•1- 68 6.1 827.17 68.00 68.00 MinPts ®i 69.09 68.59 70.21 243.37 243.37 MinPt-CtCI 72.15 68.30 54.43 299.00 299.00 MinPt-O-EOU 72.29 68.97 68.26 49.89 319.00 319.00 MinPt-O-ADP 187.13 159.85 147.18111111116E 1194.18 1180.28 MinPt-O-SF 2903.45 2863.29 2844.0: 2904.94 2493.40 MinPt-O-SF 4133.3•��_®] 6435.94 3655.75 MinPt-O-SF 4056.31 3956.85 4133.31 4032.11 3982.31 6435.94 3655.75 Ming-0-SF 6840.71 3673.77 MinPts OP17-P02(P3)(Def Plan) Pass 64.00 62.08 60.75 N/A 0.00 0.00 Surface 64.001 60.44 59.62 37.80 299.00 299.00 MinPt-CtCt 64.09 60.351 59.43 34.10 329.00 329.00 MinPt-O-EOU Drilling Office 2009.1.745.0 Nikaitchuq\Oliktok Point\0111-01\OP11-101\0111-01(P4) 7/29/2010 10:36 AM Page 4 of 8 Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct•Ct(ft)I EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major 64.16 60.36 59.42 33.09 339.00 339.00 MInPI-O-ADP 208.01 179.11 165.61 7.64 1205.17 1190.55 MinP1-0-SF 4073.96 3978.89 3932.24r 43.641 5325.62 3431.76 M1nP1-0-SF 4634.79 4520.83 4464.651 41.241 6149.71 3634.39 MinPt-O-SF 4043.87 3868.52 3781.65 23.27 10521.35 3673.05 TD 1 4496.5511 4366.07 4301.64 34.88 7321.92 3672.23 MinPt-CtCt 4502.8711 4367 8811 4301 1911 33.7511 773618 3668.48 MinPts OP24-ENI#4(P2)(Def Plan) Pass 127.91 126.00 124.67 N/A 0.00 0.00 Surface 1 127.91 123.64 122.46 53.42 399.00 399.00 MinPt-CtCI 128.05 123.521 122.22 48.42 438.82 438.82 MinPt-O-EOU 128.12 123.54 122.211 47.42 448.78 448.77 MinPt-O-ADP 223.81 192.47 177.75 7.541 1286.54 1265.66 MinPt-O-SF 6157.60 6048.39 5994.58 57.21 9052.61 3684.38 TD OP18-107(P2)(Def Plan) Pass 72.00 70.09 68.76 N/A 0.00 0.00 Surface 1 72.0 68.80 68.15 54.35 250.00 250.00 Min%-CICt 72.10 68.721 67.99 47.96 280.00 280.00 MinPI-O-EOU 72.17 68.74 67.98 46.28 290.00 290.00 MinPt-O-ADP 306.54 276.90 263.04 10.99 1201.00 1186.65 MinPt-O-SF 2111.04 2064.18 2041.631 46.771 3011.81 2537.86 MinPI-0-SF 4923.31 4833.53 4789.521 55.911 5326.87 3432.24 Min Pt-O-SF 5310.27 5213.64 5166.201 56951 5624.25 3532.13 MinP1-0-SF 6156.35 6047.38 5993.691 57.331 6147.21 3634.21 MinP1-0-SF 6353.53 624360 6188.541 58.321 6220.04 3639.78 MinPI-O-SF 5614.82 5438.43 5351.04 32.11 10521.35 3673.05 TD 5523.73 5357.07 5274.541 I 10039.19 3686.72 Min%-0-SF Oliktok Point 1-1(Def Survey) Pass 88.54 86.62 85.29 N/A 0.00 0.00 Surface • 88.54 86.62 85.29 243391.93 40.10 40.10 MinPts 88.66 86.52 85.42 377.26 89.20 89.20 MinPt-O-EOU 389.38 362.88 350.581 15.76 1197.65 1183.53 Min%-0-SF 7082.46] rr 6970.3. ' 3409.52 2691.51 MinPts Oliktok Point I-1A-106(P4)(Def Plan) Pass 88.54 86.62 85.29 N/A 0.00 0.00 Surface 88.54 86.62 85.29 243391.93 40.10 40.10 MinPts 88. 86.52 85.42 377.26 89.20 89.20 MinP1-0-EOU 389.38 362.88 350.58 15.76 1197.65 1183.53 Min Pt-O-SF 6929.87 6883.01 6860.07 151031 2930.03 2504.40 MinPt-O-SF 8365.66 8232.70 8166.72 63.381 6640.47 3666.97 MinPt-O-SF _ 9541.12 9381.14 9301.64_ 60.001 7092.01 3676.35 MinP1-0-SF 9718.54 9556.82 9476.45 60451 7143.10 3676.01 Min%-0-SF 1 10287.06 10116.88 10032.28 60.79 7288.41 3673.25 TD 1 OP25 DSP01(P1)(Def Plan) Pass 1 351.771 346.93 345.47 119.76 400.00 400.00 MinPt-CtCt 352.02 346.701 345.00 102.78 457.02 457.01 MinPt-O-EOU 352.22 346.74 344.96 98.35 476.02 476.01 MinPt-O-ADP 452.00 430.73 421.08 23.261 1199.95 1185.67 MinPt-O-SF 4160.80 4141.34 4132.50 235.00 3165.34 2597.18 TD 0505-S3(P1)(Def Plan) Pass • 17887.77 17884.52 17854 971 13397.70 200.20 200.20 MinPts 17888.02 17884.28 17855.21 9823.44 250.20 250.20 MinP1-0-EOU 2713.34 2485.30 2374.24 12.19 10521.35 3673.05 TD L17888.811 17883.57 17856.01 5379.30 440.71 440.71 MinPts 2796.34 2561.91 2447 461 12.191 9559.50 3684.15 MinPt-O-SF 2749.32 2518.16 2405.41 12.17 10049.47 3688.77 MinPt-O-SF 1 2713.521 2485.471 2374 4011110111105110 10518.43 3673.15 MinPts • 0501-S2(P1)(Def Plan) Pass 1 17884.011 17880.76 17851 20 13389.78 200.20 200.20 MinPts 17884.2 17880.5111 17851.44 9817.80 250.20 250.20 MinPt-O-EOU 3911.51 3682.01 3570.00 17.44 10521.35 3673.05 TD 17885.0 17879.81 17852.24 5375.81 440.73 440.73 MinPts 3951.42 3718.16 3604.15 17.311 10041.50 3686.73 MinP1-0-SF L. 3911.761 3682.241 3570.22 17.44 10517.46 3673.18 MinPts 0411-S1(P1)(Def Plan) Pass e1 17880.41 17877.161 17847.601 13382.16 200.20 200.20 MinPts 17880.7 17876.90 17847.92 9339.36 260.20 260.20 MinPt-O-EOU 5109.49 4878.14 4765.02 22.56 10521.35 3673.05 TD L 17881.42 17876.19 17848.62 5391.87 438.02 438.02 MinPts 17881.43 17876.19 17848.62 5376.87 440.74 440.74 MinPt-O-EOU 1 5109.891 4878.51 4765.381 22.56 10515.57 3673.25 MinPts 0407-SE1(P1)(Del Plan) Pass 17876.7 17873 51 17843.9 1 13374.39 200.20 200.20 MinPts 17877.011 17873.271 17844.20 9806.83 250.20 250.20 MinPt-O-EOU 6494.03 6305.66 6213.52 35.22 10521.35 3673.05 TD MIEM 17872.56 7845 001 5369.04 440.76 440.76 MinPts 6510.87 6313.82 6217.18 33.6 1 9076.99 3684.39 Min%-0-SF 6497.13 6302.951 6207.771 34.11 9575.19 3684.16 MinPt-O-ADP i,1 6489.84 6298.091 6204.15 34.52 10048.67 3686.77 MinPt-O-ADP Drilling Office 2009.1.745.0 Nikaitchuq\Oliktok Point\0111-01\OP11-101\0111-01(P4) 7/29/2010 10:36 AM Page 5 of 8 Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft) EOU(ftL Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major 6489.50 6298.05 6204.27 34.58 10062.94 3686.80 MinPt-O-EOU I 6488.90 6298.71 6205.62 34.83 10116.08 3686.39 MinPt-CtCt 0308-SE2(P1)(Def Plan) Pass I1 17861.98 17858.72 17829.1 13342.40 200.20 200.20 MinPts 17862.23 1785848 17829.42 9773.72 250.20 250.20 MinPt-O-EOU 7694.41 7503.30 7409.46 40.98 10521.35 3673.05 TO e MEME s 5353.26 440.82 440.82 MinPts 7697.44 7499.511 39.50 9574.70 3684,16 MinPt-O-ADP 7696.•. 7499 241 7402.45 39.74 9598.28 3684,24 MinPt-O-EOU 7690.12 749409 7399.04 40.06 10047.70 3686.76 MinPt-O-ADP 7689.78 MMENI 7399.19 40.12 10060.76 3686.80 MinPt-O-EOU 7689.11 7495.73 7400.70 40.44 10113.28 3686.43 MinPl-CICt 0210-SE3(P1)(Def Plan) .Pass 17851. 17848.13 17818.5 13318.88 200.20 200.20 MinPts 17851. 17847.92 17818.77 10241.49 24020 240.20 MinPt-O-EOU 8929.90 8742.76 8650.57 48.42 10521.35 3673.05 TD 17847.22r 17819.6: 5330.01 440.87 440.87 MinPts 17852.4•.MEEMEI'I 17819.68 5317.95 443.60 443.60 MinPt-O-EOU 8939.37 8738.65, 8639_ 45.06 8641.89 3672.75 MinPt-O-ADP ' 8931.47 8734.34 8637.00=as 9074.96 3684.40 MinPt-O-SF • 8923.04 8728.25 46.38 9560.99 3684.15 MinPt-O-ADP • 8922.5 I 8728.20 8632.26 46.49 9568.92 3684.15 MinPt-O-EOU I 8919.57 872818 8633.7 47.22 10039.27 3686.72 MinPts 8919.41 8728.72 8634.67 47.41 10070.09 3686.79 MinPl-CtCt 0110-SE4(P1)(Def Plan) Pass 9.871 1177883366A621 17807.0 .65 202 200. MinPts 178417830.0 17836.41 17807.28 1016613292.52 220040..0 240.20 20 MinPt-O-EOU 10101.36 9914.38 9821.98 54.65 10521.35 3673.05 TO ^_� 17808.1: 5298.58 443.65 443.65 MinPts ' 10105.01 9910.6311: :l. 52.49 9574.76 3664.16 MinPI-0-ADP 10097.17 9905.66 9810.89 53.26 10047.59 3686.76 MinPt-O-ADP 10096.81 9905.63 9811.03 53.35 10058.57 3686.80 MinPt-O-EOU 10095.90 9906.60 9812.99 53.91 10116.11 3686.38 MinPt-CtCt 0108-SE5(P1)(Def Plan) Pass 17838.3 17835.1 17805.5 1 13289.20 200.20 200.20 MinPts 17838. 17834.91 17805.77 10163.57 240.20 240.20 MInPt-O-EOU i 11297.84 11112.28 11020.31 61.41 10521.35 367305 TD '8 f0 17806.6• 5296.99 443.66 443.66 MinPts 1 11302.35 11108.90 •1�j_ 58.90 9575.97 3684.16 MinPt-O-ADP 11300.54MCCE. 11013.32 59.34 9598.17 3684.24 MinPt-O-EOU 11294.24 11103.66 11009.18 59.76 10045.83 3686.75 MinPt-O-ADP 11293.74=MI 11009.36 59.90 10059.55 3686.80 MinPt-O-EOU 11292.69 11104.78 11011.62 60.60 10119.50 3686.33 MinPt-CtCt 0106-SE6(P1)(Def Plan) Pass • ., 17832.92 17803. 13284.07 200.20 200.20 MinPts 17836.37 17832.7 17803.56 10169.65 240.20 240.20 MinPt-O-EOU 12496.20 12311.65 12220.17 68.29 10521.35 3673.05 TD MIME 17832 00 151=1 5306.83 440.94 440.94 MinPts 17837.28 17832.00 17804 47 5296.10 443.67 443.67 MinPt-O-EOU 12500.94 12308.1' 65.39 9575.72 3684.16 MinPt-O-ADP 12498.9 algallE. 12213.00 65.93 9598.22 3684.24 MinPt-O-EOU 12492.68 12302.88 12208.78 66.37 10045.49 3686.75 MinPt-O-ADP 12492.1: 12208.96 66.53 10058.40 3686.80 MinPt-O-EOU E '1 12303.99 12211.28 67.35 10117.65 3686.36 MinPt-CtCt 12496.20 12311.64 12220.171 68.291 10520.90 3673.07 MInPt-O-SF 0104-SE7(P1)(Def Plan) Pass 17834.74 17831.49 17801.r' 13280.68 200.20 200.20 MinPts 178350 17831 25 17802.21 9618.15 250.20 250.20 MinPt-O-EOU 13697.94 13514.70 13423.88 75.41 10521.35 3673.05 TD LOWEEKEEMMIl 17803.01 5307.47 440.95 440.95 MinPts 13702.49 13510.61 1I'1I 72.01 9574.63 3684.16 MinPt-O-ADP 13700.3 MOM 13415.89 72.65 9597.44 3684.24 MinPt-O-EOU 13694.09 13505.36 Ma= 73.17 10046.91 3686.76 MinPt-O-ADP 13693.72 REM 13411.94 73.31 10056.00 3686.79 MinPt-O-EOU MEM 13506.64 13414.53 74.32 10117.22 3686.37 MinPt-CtCt 13697.86 13514.62 13423.81 MOE 10515.04 3673.27 MinPI-0-SF Nikaitchuq 3PB2(Def Survey) Pass 18489.12 18487.16 18456.311 379414.98 51.00 51.00 MinPts 18489 92 18486.18 18457 11 10136.57 250.80 250.80 MinPt-O-EOU 14251 40 14124 26 14061.49 113.51 10521.35 3673.05 TD 18490.71 18485.37 18457.90 5398.98 445.88 445.88 MinPts YI 14256.06 14129.04 14066.33 113.651 10513.96 3673.30 MinPts Nikaitchuq 3PB3(Def Survey) Pass I 18489.121 18487.16 18456.31 379414.98 51.00 51.00 MinPts 18489.92 18486.18 18457.11 10136.57 250.80 250.80 MinPt-O-EOU 14376.58 14248.80 14185.70 113.92 10521.35 3673.05 TD 18490.71 18485.37 18457.90 5398.98 445.88 445.88 MinPts 14378.71 14250.96 14187.88 113.971 10519.05 3673.13 MinPts Nikaitchuq 3PB1(Def Survey) Pass 18489.121 18487.16L 18456.311 379414.98 51.00 51.00 MinPts Drilling Office 2009.1.745.0 Nikaitchuq\Oliktok Point\0111-01\OP11-101\0111-01(P4) 7/29/2010 10:36 AM Page 6 of 8 Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft) EOU(ft L Dev.(ft) Fact. MD(ft) 1 TVD(ft) Alert 1 Minor I Major 18489.921 1848618 18457.11 10136.57 250.80 250.80 MinPt-O-EOU 14309.41 14182.61 14120.01 114.28 10521.35 3673.05 TD II 18490.711 18485.371 18957... 5398.98 445.88 445.88 MinPts `I 14311.891 14185.16 14122.59 114.361 10517.29 3673.19 MinPts 0101-SE8(P1)(Del Plan) Pass 17832.59 17829.33 17799.7 13275.61 200.20 200.20 MinPts 17832.84 17829.07 17800.03 9629.47 250.20 250.20 MinPt-O-EOU 14899.29 14717.54 14627.47 82.70 10521.35 3673.05 TD 012B1M17828.361 17800.8 I 5307.71 440.96 440.96 MinPts 14918.80 14724.85 14628.68® 9081.97 3684.39 MinPt-O-SF 14904.01 14713 38 14618.87 78.84 9575.91 3684.16 MinPt-O-ADP 14901.71�� 14619.37 79.61 9599.00 3684.24 MinPt-O-EOU 14895.55 14708.00 II= 80.10 10046.06 3686.75 MinPt-O-ADP 14895.0•• 14615.23 80.29 10057.45 3686.79 MinPt-O-EOU 14893. 14709.36 14617.96 81.47 10117.38 3686.36 MinPt-CtCt 14899.29 1471734 146274 MOE.. 10520.92 3673.06 MinPt-O-SF • Nikaitchuq 3(Def Survey) Pass 18489.12 18487.16 18456.31 379414.98 51.00 51.00 MinPts • 18489.92 18486.18 18457.11 10136.57 250.80 250.80 MinPt-O-EOU 14376.58 14248.80 14185.70 113.92 10521.35 3673.05 TD • 18490 71 10485 37 8457 90 5398.98 445.88 445.88 MinPts 15142.68 15022.43 14963.11=NM 9560.86 3684.15 MinPt-O-SF 14932.73 14808.36 14746.98 ME1L31 10045.28 3686.75 MinPt-O-SF 14908.05 14783.91 14722..'NEM 10062.48 3686.80 MinPt-O-SF 15633.76 15516.59 15458.81 8543.80 3671.90 MinPt-O-SF 15326.71 15210.64 15153.41 I 9020.33 3684.07 MinPt-O-SF 11111E220 MIMI WW1 133.90 9057.55 3884.39 MinPts Nikaitchuq 2(Def Survey) Pass 19065.22 19060.5011 19032.42 6794.38 409.37 409.37 MinPt-O-EOU 1 16781.4811 16678.64 16628.43 167.09 7455.41 3667.47 MinPt-CtCt 16781.48 16678.641 16628.43 167.08 7455.50 3667.47 MinPts 16794.56 16691.53 16641.24 166.96 7462.94 3667.24 MinPt-O-SF 17830.55 17725.72 17674.261 173.211 7726.20 3668.30 MInPt-O-SF 21074.75 20954.19 20894.711 177.141 8015.02 3671.74 MinPt-O-SF Klgun 1(Def Survey) Pass 17138.09 17135.38 MEMO 21436.50 162.14 162.14 MinPts 17138.24 EM13 17105.43 16079.96 197.17 197.17 MinPt-O-EOU =Mg=MI .. . 5677.04 451.24 451.24 MinPts 17139.71=cm 17106.90 5633.87 454.20 454.20 MinPt-O-EOU 17143.68 17138,29 17110.87 MEM 508.18 508.16 MinPt-O-SF Klgun 1 PB1(Def Survey) Pass 17138.09 17135.38®1 21436.50 162.14 162.14 MinPts 17138.2.MEM 17105.43 16079.96 197.17 197.17 MinPt-O-EOU IIIIII 1.1n111E 17106.90 5677.04 451.24 451.24 MinPts 17139.71 17106.90 5633.87 454.20 454.20 MinPt-O-EOU 17143.68 17138.29 17110.871 4933.971 508.18 508.16 MinPt-O-SF Tuvaaq ST 1(Def Survey) ' Pass 17138.09 17135.38 MI= 21436.50 162.14 162.14 MinPts 17138.24 EMI 17105.43 16079.96 197.17 197.17 MinPt-O-EOU • MIME MEER 17106.9.1, 5677.04 451.24 451.24 MinPts • 1713971 mum 17106.90 5633.87 454.20 454.20 MinPt-O-EOU • • 17143.68 17138.29 17110.871 4933.971 508.18 508.16 MinPt-O-SF 0112-FN8(P1)(Def Plan) Pass 17841.38 17838.12 17808.57 13296.11 200.20 200.20 MinPts 17841. 17837.91 17808.78 10177.00 240.20 240.20 MinPt-O-EOU ' 17842. 17837.21 17809.691 5301.23 443.65 443.65 MinPts 17847.07 17841.38 17814.27 4727.321 505.61 505.59 MinPt-O-SF 0201-FN7(P1)(Def Plan) Pass 17843.56 17840.30 17810.75 13301.15 200.20 200.20 MinPts 17843.77 17840.10 17810.96 10185.91 240.20 240.20 MinPt-O-EOU I 17844.68 1783940 17811.871 5304.19 443.64 443.63 MinPts !I 17849.26 1784357 17816.45 4729.261 505.59 505.58 MinPt-O-SF 0204-FN6(P1)(Def Plan) Pass 17845.88 17842.62 17813.07 13306.42 200.20 200.20 MinPts 17846.0 1784242 17813.27 10203.01 240.20 240.20 MinPt-O-EOU ' I 17846. 17841.71 17814.1 5308.37 443.82 443.62 MinPts 17851.57 17845.88 17818.77 4731.291 505.57 505.56 MinPt-O-SF 0205-N8(P1)(Def Plan) - Pass 17852.35 17846.66 17819,54 MEM 505.57 505.55 MinPt-O-SF 0206-FN5(P1)(Def Plan) Pass 17847.43 17844.17 17814.62 13309.95 200.20 200.20 MinPts 17847.62 17843.96 17814.82 10224.42 240.20 240.20 MinPt-O-EOU 1 17848.531 17843.26 17815.7 5312.56 443.62 443.61 MinPts 17853.12 17847.43 17820.32 4732.651 505.56 505.55 MinPt-O-SF III 0207-N7(P1)(Def Plan) Pass 17854.70 17849.01 17821.89=En 505.55 505.53 MinPt-O-SF Drilling Office 2009.1.745.0 Nikaitchuq\Oliktok Point\0111-01\OP11-101\0111-01(P4) 7/29/2010 10:36 AM Page 7 of 8 Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert I Status Ct-Ct(ft)I EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor Major 0212-FN4(P1)(Def Plan) ass 17852.99 17849.73 17820.18 13322.48 200.20 200.20 MinPts 17853.18 17849.52 17820.37 10257.20 240.20 24020 MinPt-O-EOU 1 17854.08 17848.82 17821.24 5333.96 440.86 440.86 MinPts 17854.09 17848.82 17821.28 5321.36 443.59 443.59 MinP1.0-EOU 17858.68 17853.00 17825.87 MEM 505.52 505.50 MinPt-0-SF 0304-N6(P1)(Def Plan) Pass 17863.49 17857.81 17830.69 4741.58 50548 505.47 MinPt-O-SF 0307-FN3(P1)(Def Plan) Pass 17861.14 17857.88 17828.33 13340.55 200.20 200.20 MinPts 17861.41 17857.66 17828.60 9738.21 250.20 250.20 MinPt-O-EOU 1 17862.21, 17856.95 17829.40} 5346.84 440.82 440.82 MinPts 17866.83 17861.14 17834.02,1 4744.411 505.46 505.44 MinP1-0-SF 0311-N5(P1)(Def Plan) Pass 17870.22 17864.54 17837.42 WM 505.43 505.42 MinPt-O-SF 0312-FN2(P1)(Def Plan) Pass 17865.39 17862.14 17832.58 13349.86 200.20 200.20 MinPts I 17865.64 17861.90 17832.83 9777.15 250.20 250.20 MinPt-0-EOU I` 17866.44 17861.19 17833.63_11 5356.25 440.81 440.80 MinPts 17871.08 17865.40 17838.27 4747.981 505.43 505.41 MinPt-O-SF 0601-W D1(P1)(Def Plan) Pass 17872.85 17867.17 17840.04 MEE 505.42 505.40 MinP1-0-SF 0402-N4(P1)(Def Plan) Pass 17877.09 17871.41 17844.28 MEG 505.39 505.37 MinPt-O-SF 0403-FNI(P1)(Def Plan) Pass 17872.28 17869.03 17839.48 13364.79 200.20 200.20 MinPts 17872.52 17868.78 17839.72 9799.98 250.20 250.20 MinPt-O-EOU R 17873.32 17868.08 17840.51 5364.81 440.78 440.78 MinPts 1787797 1787229 1784516 4753.721 505.38 505.37 MinP1-0-SF 0406-N3(P1)(Def Plan) Pass 17880.64 17874.97 17847.84 MEM 505.36 505.35 MinPt-0-SF 0408-N2(P1)(Del Plan) Pass 17883.35 17877.68 17850.54 MEE 505.35 505.33 MinPt-O-SF 0412-N1(P1)(Def Plan) Pass 17887.02 17881.34 17854.211 4761.141 505.32 505.31 MinPt-0-SF 0502-W1(P1)(Def Plan) Pass 17890.63 17884.96 17857.82 4764.08 505.30 505.28 MinPt-0-SF 0506-W2(P1)(Def Plan) Pass 17894.40 17888.73 17861.59=MI 505.27 505.26 MinPt-0-SF 0508-W3(P1)(Def Plan) Pass 17897.26 17891.60 17860.461 4769.421 505.26 505.24 MinPt-0-SF 0510-W4(P1)(Def Plan) Pass 17899.19 17893.53 17866.39 4770.97 505.24 505.23 MinPt-O-SF 0512-W5(P1)(Def Plan) Pass 17901.14 17895.47 17868.331 4772.521 505.23 505.22 MinPt-0-SF Nikaitchuq 4(Def Survey) Pass I 1857.89 18526.92 18496.08 380854.07 51.00 51.00 MinPts 18529.4$ 18526.57 18496.66 18870.12 170.92 170.92 MinPl-0-EOU • 1 18531.19 18525.82 18498.38 5363.32 458.56 458.56 MinPts 18531.20 18525.81 18498.39 5331.81 461.65 461.65 MinPt-O-EOU 18533.96 18528.20 18501.15®i 510.48 510.47 MinPt-0-SF Nikaitchuq 4PB1(Def Survey) Pass 18528.89 18526.921 18496.081 380854.07 51.00 51.00 MinPts j N 18529.47' 18526.57 18870.14 170.92 170.92 MinPt-0-EOU Y 18531.19 18525.82 16498.381 5363.32 458.56 458.56 MinPts 18531.20 18525.81 18498.39 5331.81 461.65 461.65 MinPt-O-EOU 18533.96 1852820 18501.15 MEMSEI 51048 510.47 MinPt-O-SF Nikaitchuq 1(Def Survey) Pass 18566.63 18560.86 18533.82 510.83 510.81 MinPt-O-SF Drilling Office 2009.1.745.0 Nikaitchuq\Oliktok Point\0111-01\0P11-101\0111-01(P4) 7/29/2010 10:36 AM Page 8 of 8 Schlumberger TRAVELING CYLINDER PLOT Client: ENI NoGo Region EOU's based on: Well: OI11-01 Oriented EOU Dimension Field Nikaitchuq N NoGo Region Anti-Collision rule use. Structure: Oliktok Point Minor Risk- •aration Factor A ' Date: July 29,2010 iNorth 350 0 10 340 • 20 OP10-Po• ` `fir 330 ' �I'�. =-sowi) 320 $0 . ■,•081�PB1 �a 310 - �140 Q9e • 4�,,„ ,, 50 300 :� / 4t, �'�' ,,fir A1 -105(P3) q�I /0........11._ o , 50, ..ass- .280 k‘,..:#1,11): : ', vici_g.....4 .,„7-104(P2) 270 '_ - a+ _ _� 90 260 /�,��r,.� C�' 100 _'/iii. .±.. :" 250 ,ar14,.j�t'. \ . 'J�ilr•� p4 110 240 i ` ,, o° 120 '1610 230 71/ / 130 T 220 140 210 150 200 160 190 180 170 Well Ticks Type: MD on OI11-01(P4) Calculation Method: Normal Plane Ring Interval: 10.00 ft Azimuth Interval: 10.00 deg Scale: 1 INCH=20.00 ft Schlumberger 1 TRAVIIING CYLINDER PLOT Client: ENI NoGo Region EOU's based on: Well: 0I11-01 Oriented EOU Dimension Field: Nikaitchug N NoGo Region Anti-Collision rule used: Structure: Oliktok Point d Minor Risk- •oration Factor Date: July 29,2010 ■1111/f 1 North 350 0 10 340 20 330 .; 140 , 'a-••-Sli(P1) 320 12, • JI/r/%, 40 310 101 1 'I/ �� 50 ,2,\3• Nrl� . 0P08-04PB1 0.•■■■■■ 10A 300 i.��►`llti-z 80 60 290 ify. '� 1 -.4: , 60 ∎'/fir, ISM(i ON \ 40 _ ,280 ►�`�41111:1::.1 _•�� i// 80 ' ., 20 00 la land'270 ` 90/ G, i 260 ►, ■.4....r ,- oo ". `` 100 fr.4112WitipOr:,, .. *a it•cso a, *iv ,_.., 250 f"" o�, v , 110 , 1/1411 ir• p i r 240 �. 3-103(•1) o� 120 ;%F1�4-108 Ii•1) \ It* 11111 230 11/4 130 all" 220 210 � 50 200 160 190 180 170 Well Ticks Type: MD on 0111-01(P4) Calculation Method: Normal Plane Ring Interval: 20.00 ft Azimuth Interval: 10.0 deg Scale: 1 INCH=50.00 ft I Schlumberger TRAVELING CYLINDER PLOT Client: ENI NoGo Region EOU's based on: Well: OH 1-01 Oriented EOU Dimension Field: Nikaitchuq .■ Structure: Oliktok Point NoGo Region Anti-Collision rule used: Minor Risk-Se.aration Factor Date: July 29,2010 North 350 0 10 340 300 20 330 280 ®� 'W*430 320 } %40 �� 240,V 220 310 ,. 200 , 50 � 180 �� ♦ ♦ \ 300 160 60 . 140 ' , A•tit 120 290 �. 20 '•�,, ��.� 100 4 8-04PB1 - liii . 280 %_�- 4. 4 60 . ii i Lik. 80 I II �1`f: V'Not 270 ', 0 20 111116111111111111111111111 \\I 90 3 .•• O0 6,\-' ,q le d Jo O 0cA /^ � �i cb 260 "��\�. O Oa `,� C �Y-'L 1_ o 00 �` 100 ��r ill\ ��-�, ' ■Vi 00 �t /'a 4,`\ ; O4 �•, / �� /� o� c� o ov 250 �'�j,'��a i o oti 110 t›*,il.I .6›. • \ 4 WA. V 7 6°' 4,. , ' 240 \ �•� It- �, 04, oow 120 c`,,�ji ,/\ \f;r �ft/ia` 230,1 ir �i�f l 1 130 �� k` 220 4 Vie f21 � 140 210 '�r `�'/r ' 150 V OP26-DSPO2 200 160 190 180 170 Well Ticks Type: MD on 0111-01(P4) Calculation Method: Normal Plane Ring Interval: 20.00 ft Azimuth Interval: 10.0 deg Scale: • 1 INCH=100.00 ft Driiiing Hazards Summary 16" Open Hole / 13-3/8" Casin2 Interval Hazard Risk Level Mitigation Strategy Broach of Conductor Low Monitor continuously during interval. Gas Hydrates Moderate , Control drill, Reduced pump rates, Reduced drilling fluid temperatures, Additions of Lecithin. Running Sands and Low Maintain planned mud parameters, Increase Gravels mud weight, use weighted sweeps. Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets),pumping out 12-1/4" Open Hole / 9-5/8" Casin2 Interval Hazard Risk Level Mitigation Strategy Running Sands and Low Maintain planned mud parameters, Increase Gravels mud weight, use weighted sweeps. Gas Hydrates Low Control drill, reduced pump rates, reduced drilling fluid temperatures, additions of Lecithin. Stuck Pipe Low Good hole cleaning, pre-treatment with lost circulation material, stabilized BHA, decreased mud weight Abnormal Reservoir Low . BOP training and drills, increased mud weight. Pressure Lost circulation Low Reduced pump rates, mud rheology, LCM Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets),pumping out 8-1/2" Open Hole /5-1/2" Liner Interval Hazard Risk Level Mitigation Strategy Abnormal Reservoir Low Stripping drills, shut-in drills, increased mud Pressure weight. Stuck Pipe Low Good hole cleaning, PWD tools, hole opener runs, decreased mud weight Lost Circulation Low Reduced pump rates, mud rheology, LCM Hole Swabbing on Trips Moderate . Trip speeds, proper hole filling (use of trip sheets),pumping out, backreaming Drilling Hazards Summary.doc 6/3/2010 2:53:00 PM ., | ., % g ■� \ |I | � | �■ K ! _\ t .2 g 101 ■ � 0 o_ z \/ a_ / k§ § ■ in\o§\ 6\\� oL0( A'(D k | \ | y«3\6 y<®5 i-%5 y�kE | 2| ■ 3®S/ </d ®Ear �B§� I\\%� \\\� \//\ \\\� § II \ § $ �uz — z _,1 - z a b | | %%mu_\ \»\j (Z) N %/zk \ / 2 // \ \ -\ § | m \ | h 4i i§ «\» iy » °¥q �� k k§ ■ \»» %3 . §e �m jI �\� G§ % 6« NI F . - L - I — U $ O � " A,- \ 1-----__J L— g � ƒ © a /� g r- 7�2 E_ 2 CO O �� / 1/ _4\ '- 0 - - - - 4 CC A o e --7", I z O L., %3 \ %E °\ ( I 0¥§ \2 o 0 %3 3 ©z/ �¢ - �(§ �0 4m I / - I l filliiiirilli aikNra a%114 u) E L. a..WIP 20 u_ co AIN lot dilbk 11410 e , ... \■\ 0,1 kin.... . 1 , w/-- IcFAIL 741\111/ ii..1,6114i\VP 01140 , 4 ... , 4 ' i diVii■ A . ,.910, \Air 0 , ("I 1 I. \elk 11.1'\ RA 0111111411\11k) - IMF A 'I- ' ' alik\IIP)11,\II -10■11(11\1. . ..., . » a) 0 .‘ 0to E3S 1 !Id .., ' ...... br.. E _C TO TI:1 al 0 t C') C C 2 icr) ' 0 _ (I) ‘ a, CC CC (,., c - Cl) -c cc C C C .y) . , i4 fil cf) E2 o 2 -0 o ' H TS a) a) a) 0 EEEc0 , 1.7, tio as as ' T' C) C) C) co ,, a) - o o o u) o , , CI) , T 2 76- ZID ZO CD 'CIO , c(c)i > co -...- - -.... - - co > C To a) w ,- ,- ,- 7 0 .4- (I)c:i co - g , ,__-..., 0 0 > r3 -F2 s 0 g h, . , ,, 0 1 Tz Ta 1 = E in (0 CO 0 ' - -- - z CC Z '- cc5 41•1111K ( -1-)H-7 El) ti _ -__ gi X i - 34 ■ j I i 1 1 g a C P ii 1 1 I► u�EN I _ ��■ r lz U uJ LL d gc I h� z N d icul ,,'" , ,, ,t I ii I ,,, a N "a __ ® Uil° 6 - ��p�z 3 .:...... o m W - 2< m p of 1!I 131:R ri Wil ;1111 22 N�1 N •„, 1 W” Nei\ \ /, I N (7 MI: X _ U tO 12 s ~~ --- _— Z I r w w Y m V\LY a /�R a H N > k !! kI 8 aa17 : .S/t S-.l k N Schlumberger Ce m CAD E*well cementing recommendation for 13.375' Surface Casing Operator : Eni Petroleum Well : 0111-01 Country : USA Field : Nikaitchuq State : Alaska Prepared for : Mr.Jason Brink Location : North Slope-Alaska Proposal No. : Draft v1 Service Point : Prudhoe Bay,Alaska Date Prepared : 8-5-2010 Business Phone : 907-659-2434 FAX No. : 907-659-2538 Prepared by : Tony Stafford Phone : 907-273-1700 E-Mail Address : tstafford@slb.com O� C L ,, -9'CAT E .; Disclaimer Notice: This information is presented in good faith,but no warranty is given by and Schlumberger assumes no liability for advice or recommendations made concerning results to be obtained from the use of any product or service.The results given are estimates based on calculations produced by a computer model including various assumptions on the well,reservoir and treatment. The results depend on input data provided by the Operator and on estimates as to unknown data and can be no more accurate than the model,the assumptions and such input data.The information presented is Schlumberger's best estimate of the actual results that may be achieved and should be used for comparison purposes rather than absolute values.The quality of input data,and hence results,may be improved through the use of certain tests and procedures which Schlumberger can assist in selecting. The Operator has superior knowledge of the well,the reservoir,the field and conditions affecting them.If the Operator is aware of any conditions whereby a neighboring well or wells might be affected by the treatment proposed herein it is the Operator's responsibility to notify the owner or owners of the well or wells accordingly. Prices quoted are estimates only and are good for 30 days from the date of issue.Actual charges may vary depending upon time,equipment,and material ultimately required to perform these services. Freedom from infringement of patents of Schlumberger or others is not to be inferred. *Mark of Schlumberger Client : Eni Petroleum Well : 0111-01 Schlumberger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing Section 1 : well description Configuration : Casing Stage : Single Rig Type : Land Mud Line : 0.0 ft Total MD : 2357.0 ft BHST : 50 degF Bit Size : 16 in ft (x 1000) psi < 0 1 2 L Frac Pore ......•. .......... Permafrost ........... 1 , • N G J Well Lithology Formation Press. Page 2 0111-01.cfw,08-05-2010; LoadCase Surface Casing.Version wcs-cem460_14 Client : Eni Petroleum Well : 0111-01 SchIehrger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing Previous String MD OD Weight ID (ft) (in) (lb/ft) (in) 160.0 20 169.0 18.376 Landing Collar MD : 2277.0 ft Casing/liner Shoe MD : 2357.0 ft Casing/Liner MD OD Joint Weight ID Grade Collapse Burst Thread (ft) (in) (ft) (Ib/ft) (in) (psi) (psi) 2357.0 13 3/8 40.0 68.0 12.415 L-80 2270 5020 BTC Mean OH Diameter : 16.000 in Mean Annular Excess : 163.2% Mean OH Equivalent Diameter: 19.541 in Total OH Volume : 814.9 bbl (including excess) Caliper and Hole Size Data MD Caliper Excess Equiv.Diem. (ft) (in) (%) (in) 1867.0 16.000 200.0 20.254 2357.0 16.000 35.0 16.822 Page 3 0il1-01.cfw;00-05-2010: LoadCase Surface Casing;Version wcs-cem460_14 Client : Eni Petroleum Well : 0111-01 Slberger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing Max. Deviation Angle : 44 deg Max. DLS : 3.517 deg/100ft Directional Survey Data MD TVD Deviation Azimuth Dogleg Sev. (ft) (ft) (deg) (deg) (deg/100ft) 0.0 0.0 0.0 340.0 0.000 100.0 100.0 0.0 340.0 0.000 200.0 200.0 0.0 340.0 0.000 300.0 300.0 0.0 340.0 0.000 400.0 400.0 0.0 340.0 0.000 500.0 500.0 1.5 340.0 1.500 600.0 599.9 3.8 340.0 2.250 700.0 699.5 6.0 340.0 2.250 800.0 798.7 8.3 340.0 2.250 900.0 897.4 10.5 340.0 2.250 1000.0 995.1 14.0 340.0 3.500 1100.0 1091.3 17.5 340.0 3.500 1200.0 1185.7 21.0 340.0 3.500 1300.0 1277.9 24.5 340.0 3.500 1382.6 1352.2 27.4 340.0 3.498 1400.0 1367.6 27.5 340.0 0.518 1500.0 1456.2 28.0 340.0 0.500 1600.0 1544.3 28.5 340.0 0.500 1700.0 1631.9 29.0 340.0 0.500 1800.0 1719.2 29.5 340.0 0.500 1900.0 1806.1 30.0 340.0 0.500 1953.3 1852.2 30.2 340.0 0.487 2000.0 1892.2 31.9 340.1 3.517 2100.0 1975.4 35.4 340.3 3.502 2200.0 2055.1 38.9 340.5 3.492 2300.0 2131.0 42.4 340.6 3.501 2357.0 2172.5 44.3 340.7 3.475 Formation Data MD Frac. Pore Name Lithology (ft) (lb/gal) (lb/gal) 120.0 11.00 8.43 Permafrost Sandstone 1900.0 12.00 8.43 Permafrost Sandstone 2430.0 13.00 9.20 Sandstone Geothermal Temperature Profile MD TVD Temperature Gradient (ft) (ft) (degF) (degF/100ft) 0.0 0.0 20 0.0 1900.0 1806.1 32 0.7 2357.0 2172.5 50 1.4 Page 4 0111-01.cfw;08-05-2010; LoadCase Surface Casing;Version wcs-cem460_14 Client : Eni Petroleum Well : 0111-01 Schlirgcr String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing ft degF ft o_ 0 9n 40 60 n .gin 500 750 _—Geoth.Profile I Hod.Depart. I ij L[, :C■_■■■ ■- 1 N ■ 111■ ■■ 0 - ■ ■■■■■ms Li, ■■!l Lue ■■■ ci ' 11111111111111111111111 gem o I r- �■■■■um _u■ r \ ± j � o 0 �I. o _ 111111l�iil■:.....:C= ■■■■■■■■■■ I I - i"i I o , . � ' kr - . 1:� - co � #. 14# "•:C=::' kNL4\-..o- I 1 t ;ii r 1. I ~ ■N■■►1. ■■%-- r.. .... iii. _ .. ,_ -onus � N ■= ■■■■■■►■ ■� .......�..MIE o Ln 111111111111111111111111111111111111111 MI o 1.__ � N _ _ ._. _ Minn . O 0-i— N Temperature Hori. Departure Section 2: fluid sequence Job Objectives: Cement to Surface in Permafrost Original fluid Mud 9.50 lb/gal Pv: 12.000 cP Ty:7.00 lbf/100ft2 Displacement Volume 340.9 bbl Total Volume 910.7 bbl TOC 0.0 ft Fluid Sequence Name Volume Ann. Len Top Density Rheology (bbl) (ft) (ft) (lb/gal) MUDPUSH II 100.0 0.0 10.10 Pv:24.000 cP Ty:10.00 lbf/100ft2 Lead Slurry 406.0 1857.0 0.0 10.70 k:1.67E-4 Ibf.s^n/ft2 n:0.977 Ty:9.98 lbf/100ft2 DeepCRETE 63.8 500.0 1857.0 12.00 k:7.50E-2 lbf.s^n/ft2 n:0.372 Ty:4.15 lbf/100ft2 Mud 340.9 0.0 9.50 Pv:12.000 cP Tv:7.00 lbf/100ft2 Page 5 0111-01.cfw;08-05-2010 LoadCase Surface Casing Version wcs-cem460_14 Client : Eni Petroleum Well : 0111-01 Schlmihrger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing Static Security Checks: Frac 5 psi at 160.0 ft Pore 19 psi at 160.0 ft Collapse 2040 psi at 2277.0 ft Burst 5020 psi at 0.0 ft Csg.Pump out 52 ton ft (x 1000) psi o- 0 I 0 1.5 c o- 1 E —Hydrostatic —Frac —Pore IF o ml o— ii 1 II 11 cv 1 I i 1 1 - iiom ! 0 CO— Fluid Sequence Static Well Security Page 6 0111-01.c(w;08-05-2010; LoadCase Surface Casing;Version wcs-cem460_14 Client : Eni Petroleum Well : 0111-01 SIberger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing Section 3: pumping schedule Start Job: Circulate Two Hole Volumes, Safety Meeting, Test Surface Equipment Pumping Schedule Name Flow Rate Volume Stage Time Cum.Vol lnj. Comments (bbl/min) (bbl) (min) (bbl). Temp. (degF) MUDPUSH II 6.0 100.0 16.7 100.0 80 7-Start Pumping Spacer Pause 0.0 0.0 5.0 0.0 80 4-Drop Bottom Plug Lead Slurry 5.0 406.0 81.2 406.0 80 13-Start Mixing Lead Slurry 12.0 ppg 5.0 63.8 12.8 63.8 80 16-Start Mixing Tail Slurry DeepCRETE Pause 0.0 0.0 5.0 0.0 80 18-Drop Top Plug Mud 8.5 320.0 37.6 320.0 80 49-Rig Pumps To Displace Mud 3.0 20.9 7.0 340.9 80 21-Bump Top Plug Total 02:45 910.7 bbl hr:mn End Job: Bump Top Plug, Bleed-off PSI, Check floats Dynamic Security Checks: Frac 4 psi at 160.0 ft Pore 9 psi at 160.0 ft Collapse 2040 psi at 2277.0 ft Burst 4835 psi at 0.0 ft Temperature Results BHCT 65 degF Simulated Max HCT 73 degF Simulated BHCT 73 degF Max HCT Depth 2357.0 ft CT at TOC 61 degF Max HCT Time 02:45:15 hr:mn:sc Static temperatures: At Time I (hr:mn) I (hr:mn) Geo.Temp. Top of Cement (degF) (degF) 1 20 degF Bottom Hole (degF) (degF) 50 degF Page 7 0111-01 ON,08-05-2010; LoadCase Surface Casing;Version wcs-cem460_1 4 Client : Eni Petroleum Well : 0111-01 Schlinberger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing o - I ( , ( I , Acquired Pressure Calc.WHP 5' I I CL I 0 25 50 75 100 125 150 175 Time (min) _ Fluids at 2357 ft Acquired 12 Out — -- —Acquired 0 In , 1-. 1—,_ 1 4.' ---1 m 0 Q I 1 . I as Ct 111 _ LoI k 1 1--ii - 0 25 50 75 100 125 150 175 Time (min) Page 8 0111-01.cfw;08-055-2010; LoadCase Surface Casing;Version wcs-cem480_14 Client : Eni Petroleum Well : 0111-01 SAINIkliger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing * CemCADE Client : Eni Petroleum Well :0111-01 String : 13.375'Surface Casing District : Prudhoe Bay,Alaska Country : USA o Depth= 2357 ft 0 Depth= 160 ft I cj —Frac —Pore I —a. -Hydrostatic i 1 —Hydrostatic N —Dynamc o —Dynamic v--I I I L I o 'I I co ( rn ii d 1 moo . co Y COO- N U) 2 a� '- 1 t e ai o co- c QA— v o O all t o N N B 1 ry CDI 0 100 200 0 50 100 150 200 q Time(min) Time(min) 0 Total Depth = 2357.0 ft Top of Cement= 0.0 ft *Mark of Schlumberger lmb r Page 9 0111-01 cfw;08-05-2010; LoadCase Surface Casing;Version wcs-cem460_14 Client : Eni Petroleum Well : 0111-01 Schlumberger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing Section 4: centralizer placement Top of centralization :100.0 ft Bottom Cent. MD :2337.0 ft Casing Shoe :2357.0 ft NB of Cent. Used :34 NB of Floating Cent. :34 Centralizer Placement Bottom MD Nbr. Cent./ Cent. Name Code Min.STO @ Depth (ft) Joint (%) (ft) 1917.0 23 1/2 NW-TR-13 3/8-8-TR 3 W304 21.8 577.0 2357.0 11 1/1 NW-TR-13 3/8-8-TR 3 W304 73.1 2357.0 Centralizer Description Centralizer Tests Cent. Name Code Casing Max. Min.OD Rigid Origin Hole Size Running Restoring OD OD (in) (in) Force Force (in) (in) (lbf) (lbf) NW-TR-13 3/8-8-TR 3 W304 13 3/8 16.654 15.394 No Hannover 16.000 283.26 2832.59 (1)-Centralizer performance data is based on tests by WEATHERFORD as per the current API 10D specifications Running Force Calculations: Travelling Block Weight :33 ton Friction Factor Centralizer/Formation :0.3 Total Drag Force :7 ton Hook load Down Stroke :89 ton Hook load Up Stroke :103 ton ft % cD- z A 1 60 80 100 Between Cent. + .4(4( Cent. i 1 i o I 0 `— LL14-1-1—' t' !- . 4_1____1__-: 1 rtH o I I l I O O— N . I 1 , '---ilt° 1 11 - ]-1 I ! 1 * I i 2_ Pipe Standoff Page 10 0111-01.cfw;00-05-2010: LoadCase Surface Casing;Version wcs-cem460_14 Client : Eni Petroleum Well : 0111-01 Sclillikrger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing CemCADE Client : Eni Petroleum Well :0111-01 String : 13.375""Surface Casing District : Prudhoe Bay,Alaska Country :USA ton ft 0 0 10 20 30 ■ 40 50 60 70 80 90 100 110 —Hooldoad Up —— Hooldoad Down - -- - Weight \ - Drag Force \. \. O \. a- I \. ,t1 1 N. • 1 \ . 3 5 g i \ v N 1 1 \ •. U - a 8 n o °o K)- 4 Running Forces Friction Factor=0.3 Total Depth = 2357.0 ft Top of Cement= 0.0 ft it *Mark of Schlumberger Schlunbrpr Page 11 0111-01.cfw;08-052010; LoadCase Surface Casing;Version wcs-cem460_14 Client : Eni Petroleum Well : 0111-01 Sehlmkrger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing Section 5: WELLCLEAN II Simulator ft boo p_ 20 4n 60 80 100 Std Betw.Cent. —Cement Coverage _ ,__rill. _i__ 1_______ 0 0 r TH co co- N I I - O M- Cement Coverage Fluids Concentrations Risk Mud on tl7e'•Wall z z 0-' 0 4 22, —r y— - 0 200 200 200– 200 400- 400 400 400 600- 600 600 T 600 000- 900 000 boo z„ g 1000- 1000 .E. 1000 1000 L 1200 : 120 f L 1200- 1200 f Ts. a la -0 1 400- 1 s0a o 0 400 0 1800– 1600 1800 I—_ 1._ 1600 1680= 1800 1800 — 1800 2000 2000 2000 2000 2200 22200 2200 2200 d o v 3 c I c a 2 MI Mud High NM Lov,, I 1 12 0 ppo DeepCRETE IIM Medium OM None I I Lead Slurry I I MLIDPLISH II Page 12 0111-01.crw;08-05-2010; LoadCase Surface Casing;Version wcscern460_14 Client : Eni Petroleum Well : 0111-01 ScNIkrier String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing • Section 6: fluid description Mud DESIGN Fluid No: 1 Density :9.50 lb/gal Rheo. Model :BINGHAM Pv : 12.000 cP At temp. :80 degF Ty :7.00 lbf/100ft2 Gel Strength :(lbf/100ft2) MUD Mud Type :WBM Job volume :340.9 bbl Water Type : Fresh VOLUME FRACTION Solids :4.0% Oil :96.0% Water :0.0% MUDPUSH II DESIGN Fluid No:2 Density : 10.10 lb/gal Rheo. Model : BINGHAM Pv :24.000 cP At temp. :80 degF Ty : 10.00 lbf/100ft2 Gel Strength :(lbf/100ft2) Job volume : 100.0 bbl Lead Slurry DESIGN Fluid No:3 Density : 10.70 lb/gal Rheo.Model : HERSCHEL_B. k : 1.67E-4 Ibf.s^n/ft2 At temp. :80 degF n :0.977 Ty :9.98 lbf/100ft2 Gel Strength :(lbf/100ft2) DESIGN BLEND SLURRY Name : AricticSET Light Mix Fluid : 10.367 gal/sk Job volume :406.0 bbl ! A S Dry Density : 106.26 lb/ft3 Yield :2.33 ft3/sk ✓ Quantity :979.66 sk Sack Weight : 100 lb Solid Fraction :40.4% BASE FLUID Type : Fresh water Density : 8.32 lb/gal Base Fluid : 10.367 gal/sk Page 13 0111-01 cfw;08-05-2010; LoadCase Surface Casing;Version wcs-cem460_14 Client : Eni Petroleum Well : 0111-01 Schlwohrger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing 12.0 ppg DeepCRETE DESIGN Fluid No:5 Density : 12.00 lb/gal Rheo.Model : HERSCHEL_B. k :7.50E-2 Ibf.sAn/ft2 At temp. :80 degF n :0.372 Ty :4.151bf/100ft2 Gel Strength :(Ibf/100ft2) DESIGN BLEND SLURRY Name : 12.0 PPG Lit Mix Fluid :5.043 gal/sk Job volume :63.8 bbl Dry Density : 110.20 lb/ft3 Yield : 1.58 ft3/sk Quantity :226.40 sk Sack Weight : 100 lb Solid Fraction :57.4% BASE FLUID Type : Fresh water Density :8.32 lb/gal Base Fluid :4.973 gal/sk Additives Code Conc. Function D047 0.020 gal/sk blend Antifoam D185 0.050 gal/sk blend Dispers.LT Section 7: operator summary Start Job: Circulate Two Hole Volumes, Safety Meeting, Test Surface Equipment Operator Pumping Schedule Name Flow Rate Volume Stage Time Cum Vol Comments (bbl/min) (bbl) (min) (bbl) MUDPUSH II 6.0 100.0 16.7 100.0 7-Start Pumping Spacer Pause 0.0 0.0 5.0 0.0 4-Drop Bottom Plug Lead Slurry 5.0 406.0 81.2 406.0 13-Start Mixing Lead Slurry 12.0 ppg 5.0 63.8 12.8 63.8 16-Start Mixing Tail Slurry DeepCRETE Pause 0.0 0.0 5.0 0.0 18-Drop Top Plug Mud 8.5 320.0 37.6 320.0 49-Rig Pumps To Displace Mud 3.0 20.9 7.0 340.9 21-Bump Top Plug Total Pumping Time : 02:45 hr:mn End Job: Bump Top Plug, Bleed-off PSI, Check floats Page 14 I 0111-01.cfw;08-05-2010; LoadCase Surface Casing;Version wcs-cem460_14 Client : Eni Petroleum Well : 0111-01 Sell Selloherger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing MIXING PREPARATION MUDPUSH II Volume: 100.0 bbl Density: 10.10 lb/gal Code Quantity Design Fresh water 92.046 bbl D182 552.278 lb 6.000 lb/bbl of base fluid D047 20.000 gal 0.200 gal/bbl of spacer D031 9536.741 lb 95.37 lb/bbl of spacer Lead Slurry Volume :406.0 bbl Density : 10.70 lb/gal Yield :2.33 ft3/sk Dry Phase Liquid Phase Blend: 97966 lb Design Mix Water 241.8 bbl 10.0 bbl LAS Design 8809(100 lb) 97965.859 lb Fresh water 241.821 bbl 10.001 bbl 12.0 ppg DeepCRETE Volume: 63.8 bbl Density : 12.00 lb/gal Yield : 1.58 ft3/sk Dry Phase Liquid Phase Blend: 22640 lb Design Mix Water 27.2 bbl 10.0 bbl LAS Design 12.0 PPG Lit 22639.602 lb Fresh water 26.808 bbl 9.862 bbl 0047 4.528 gal 1.666 gal 0.020 gal/sk blend D185 11.320 gal 4.164 gal 0.050 gal/sk blend Page 15 081-01.cfw;08-05-2010; LoadCase Surface Casing:Version wcs-cem460_14 Client : Eni Petroleum Well : 0111-01 Sehlffillkliger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing CemCADE Client : Eni Petroleum Well :0111-01 String : 13.375'Surface Casing District : Prudhoe Bay,Alaska Country : USA Annulus ID: 13.375 in-OD: 16.000 in _ -Tail Slurry Lead Slurry NUDPUSHII 0 -Mud (D_ M rn o d N j N_ 3 � a rn O N - U •c U_ 0 R 4.8 5.2 5.6 6.0 6.4 6.8 7.2 7.6 8.0 8.4 8.8 9.2 4 Flow Rate (bbl/min) S ■Mud Bingham:PV=12.000 cP Ty=7.00 Ibf/100ft2 ■MUDPUSH II Bingham:PV=24.000 cP Ty=10.00 Ibf/10002 3 Lead Slurry Herschel:k =1.67E-4 Ibf.snn/ft2 n =0.977 Ty=9.98 Ibf/100ft2 ■Tail Slurry Bingham:R/=81.518 cP Ty=10.51 Ibf/100ft2 *Mark of Schlumberger Sc'u ger Page 16 0111 o1.cfw,08-05-2010, LoadCase Surface Casing.Version wcs-cem460_14 Schlumberger C emCAD E*well cementing recommendation for 9-5/8" Intermediate Casing Operator : Eni Petroleum Well : 0111-01 Country : USA Held : Oliktok Point State : Alaska Prepared for : Mr.Jason Brink Location : Nabors 245E Proposal No. : Draftvl Service Point : Prudhoe Bay,Alaska Date Prepared : 8-05-2010 Business Phone : 907-659-2434 FAX No. : 907-659-2538 Prepared by : Tony Stafford Phone : 907-273-1700 E-Mail Address : tstafford©slb.com 1/ '1I 9C�ATE Disclaimer Notice: This information is presented in good faith,but no warranty is given by and Schlumberger assumes no liability for advice or recommendations made concerning results to be obtained from the use of any product or service.The results given are estimates based on calculations produced by a computer model including various assumptions on the well,reservoir and treatment. The results depend on input data provided by the Operator and on estimates as to unknown data and can be no more accurate than the model,the assumptions and such input data.The information presented is Schlumberger's best estimate of the actual results that may be achieved and should be used for comparison purposes rather than absolute values.The quality of input data,and hence results,may be improved through the use of certain tests and procedures which Schlumberger can assist in selecting. The Operator has superior knowledge of the well,the reservoir,the field and conditions affecting them.If the Operator is aware of any conditions whereby a neighboring well or wells might be affected by the treatment proposed herein it is the Operator's responsibility to notify the owner or owners of the well or wells accordingly. Prices quoted are estimates only and are good for 30 days from the date of issue.Actual charges may vary depending upon time,equipment,and material ultimately required to perform these services. Freedom from infringement of patents of Schlumberger or others is not to be inferred Mark of Schlumberger Client : Eni Petroleum Well : 0111-01 Schlumbergur String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) Section 1 : well description Configuration : Casing Stage : Single Rig Type : Land Mud Line : 0.0 ft Total MD : 6128.0 ft BHST : 86 degF Bit Size : 12 1l4 in ft (x 1000) psi < • - CI 1 2 3 ; ; L Frac . . . . . Pore • • • • • Permafrost Ii , _� ■ t~ IN Shale 41i — • G f ( _ I O _ Well Lithology Formation Press. Page 2 si11-01.ciw;08-05-2010; LoadCase 9-5/8 Intermediate Casing(a);Version wcs-cem460_14 Client : Eni Petroleum Well : 0111-01 ScIMerger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) Previous String MD OD Weight ID (ft) _ (in) (Ib/ft) (in) 2357.0 13 3/8 68.0 12.415 Landing Collar MD : 6048.0 ft Casing/liner Shoe MD : 6128.0 ft Casing/Liner MD OD Joint Weight ID Grade Collapse Burst Thread (ft) (in) (ft) (Ib/ft) (in) (psi) (psi) 6128.0 9 5/8 40.0 47.0 8.681 L-80 4760 6870 BTCM it Page 3 oil 1-01.cfw;08-05-2010; LoadCase 9-5/0 Intermediate Casing(a):Version wcs-cem460_14 Client : Eni Petroleum Well : 0111-01 SChIMIWIer String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) Mean OH Diameter : 12.250 in Mean Annular Excess : 25.0% Mean OH Equivalent Diameter: 12.823 in Total OH Volume : 602.3 bbl (including excess) Max. Deviation Angle : 86 deg Max. DLS :4.019 deg/100ft Directional Survey Data MD TVD Deviation Azimuth Dogleg Sev. (ft) (ft) (deg) (deg) (deg/100ft) 0.0 0.0 0.0 340.0 0.000 100.0 100.0 0.0 340.0 0.000 200.0 200.0 0.0 340.0 0.000 300.0 300.0 0.0 340.0 0.000 400.0 400.0 0.0 340.0 0.000 500.0 500.0 1.5 340.0 1.500 600.0 599.9 3.8 340.0 2.250 700.0 699.5 6.0 340.0 2.250 800.0 798.7 8.3 340.0 2.250 900.0 897.4 10.5 340.0 2.250 1000.0 995.1 14.0 340.0 3.500 1100.0 1091.3 17.5 340.0 3.500 1200.0 1185.7 21.0 340.0 3.500 1300.0 1277.9 24.5 340.0 3.500 1382.6 1352.2 27.4 340.0 3.498 1400.0 1367.6 27.5 340.0 0.518 1500.0 1456.2 28.0 340.0 0.500 1600.0 1544.3 28.5 340.0 0.500 1700.0 1631.9 29.0 340.0 0.500 1800.0 1719.2 29.5 340.0 0.500 1900.0 1806.1 30.0 340.0 0.500 1953.3 1852.2 30.2 340.0 0.487 2000.0 1892.2 31.9 340.1 3.517 2100.0 1975.4 35.4 340.3 3.502 2200.0 2055.1 38.9 340.5 3.492 2300.0 2131.0 42.4 340.6 3.501 2356.6 2172.2 44.3 340.7 3.497 2400.0 2202.8 45.9 340.8 3.506 2500.0 2270.2 49.4 340.9 3.501 2600.0 2333.0 52.9 341.0 3.501 2700.0 2390.8 56.4 341.1 3.501 2800.0 2443.7 59.9 341.2 3.501 2900.0 2491.2 63.4 341.3 3.501 3000.0 2533.2 66.9 341.3 3.501 3011.6 2537.8 67.3 341.3 3.434 3100.0 2571.9 67.3 341.3 0.000 3200.0 2610.6 67.3 341.3 0.000 3300.0 2649.2 67.3 341.3 0.000 3400.0 2687.8 67.3 341.3 0.000 3500.0 2726.5 67.3 341.3 0.000 3600.0 2765.1 67.3 341.3 0.000 3700.0 2803.8 67.3 341.3 0.000 3800.0 2842.4 67.3 341.3 0.000 3900.0 2881.0 67.3 341.3 0.000 4000.0 2919.7 67.3 341.3 0.000 4100.0 2958.3 67.3 341.3 0.000 4200.0 2996.9 67.3 341.3 0.000 4300.0 3035.6 67.3 341.3 0.000 Page 4 oil1-01_cfw;08-05-2010; LoadCase9-5/8 Intermediate Casing(a);Version wcs-cem460_14 I Client : Eni Petroleum Well : 0111-01 SB I berger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) Directional Survey Data MD TVD Deviation Azimuth Dogleg Sev. (ft) (ft) (deg) (deg) (deg/100ft) 4400.0 3074.2 67.3 341.3 0.000 4500.0 3112.9 67.3 341.3 0.000 4600.0 3151.5 67.3 341.3 0.000 4700.0 3190.1 67.3 341.3 0.000 4800.0 3228.8 67.3 341.3 0.000 4900.0 3267.4 67.3 341.3 0.000 5000.0 3306.1 67.3 341.3 0.000 5100.0 3344.7 67.3 341.3 0.000 5200.0 3383.3 67.3 341.3 0.000 5300.0 3422.0 67.3 341.3 0.000 5330.0 3433.6 67.3 341.3 0.000 5400.0 3459.0 70.0 341.8 3.998 5424.5 3467.2 71.0 342.0 4.019 5500.0 3491.8 71.0 342.0 0.000 5600.0 3524.4 71.0 342.0 0.000 5624.5 3532.3 71.0 342.0 0.000 5700.0 3555.5 73.2 342.4 2.997 5800.0 3581.9 76.2 342.9 3.004 5900.0 3603.2 79.2 343.5 3.003 6000.0 3619.5 82.1 344.0 2.991 6078.4 3628.7 84.4 344.4 3.002 6100.0 3630.7 85.1 344.5 3.000 6124.5 3632.7 85.8 344.6 3.024 6128.0 3632.9 85.8 344.6 0.000 Formation Data MD Frac. Pore Name Lithology (ft) (lb/gal) (lb/gal) 120.0 11.50 8.30 Permafrost Sandstone 1900.0 12.00 8.30 Permafrost Sandstone 2430.0 13.00 8.30 Shale 6128.0 14.00 8.30 Shale Geothermal Temperature Profile MD ND Temperature Gradient (ft) (ft) (degF) (degF/100ft) 0.0 0.0 20 0.0 1867.0 1777.4 32 0.7 2430.0 2223.5 50 1.3 6128.0 3632.9 86 1.8 Page 5 oi11-01.cfw;08-05-2010; LoadCase 9-5/8 Intermediate Casing(a),Version wcs-cem480_14 Client : Eni Petroleum Well : 0111-01 S �j ner String : 9-5/8 District : Prudhoe Bay,Alaska {� Country : USA Loadcase : 9-5/8 Intermediate Casing(a) ft degF (x 1000)ft 0 2111 60 90 n 1 9 3 4 5 — Geoth.Profile I I —Hort.Depart. I I I 4 _ - C' 4—o Bra I = Br_o I i �_ 1:1____I _ Riclinilliti. immumelos 1 , .=, ,11.9 :„,.....,,,E____, , . , , _ 7,.. _ , - . n. --- , j 1 , 1 . x „, „.... .............. . Li, CV 111111011111 IN . --r-t-__LA ....... . . ....164 , " _,111111111111111111111111111101011111 mmounion J (0 _Nom Nommum c ' l 1 i 19r AIL. Temperature Hod. Departure Section 2: fluid sequence Job Objectives: Zonal Isolation,TOC @ 4,769'(500'above the"N"sand) Original fluid Mud 9.50 lb/gal Pv:20.038 cP Ty:20.59 lbf/100ft2 Displacement Volume 442.8 bbl Total Volume 613.4 bbl TOC 4769.0 ft Fluid Sequence Name Volume Ann.Len Top Density Rheology (bbl) (ft) (ft) (lb/gal) MUDPUSH II 70.0 1003.9 3765.1 10.50 Pv:36.000 cP Ty:20.00 Ibf/100ft2 DeepCRETE 100.6 1359.0 4769.0 12.50 k:6.48E-3lbf.s^n/ft2 n:0.848 Ty:7.24 Ibf/100ft2 Mud 442.8 0.0 9.50 Pv:20.038 cP Ty:20.59 Ibf/100ft2 Page 6 oil1-01.cm,08-05-2010, LoadCase 9-5/8 Intermediate Casing(a):Version wcs-cem460_14 Client : Eni Petroleum Well : 0111-01 Schlumberger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) Static Security Checks: Frac 384 psi at 2357.0 ft Pore 135 psi at 2357.0 ft Collapse 4501 psi at 6048.0 ft Burst 6870 psi at 0.0 ft Csg.Pump out 70 ton ft (x 1000) psi O- 7 J I -Hydrostatic -Frac --Pore - c; - cv - - o- Ln - 0 tn _ Fluid Sequence Static \Nell Security Section 3: pumping schedule Start Job: Circulate Two Hole Volumes, Safety Meeting, Test Surface Equipment Pumping Schedule Name Flow Rate Volume Stage Time Cum.Vol Inj. Comments (bbl/min) (bbl) (min) (bbl). Temp. (degF) MUDPUSH II 5.0 70.0 14.0 70.0 80 7-Start Pumping Spacer Pause 0.0 0.0 5.0 0.0 80 4-Drop Bottom Plug DeepCRETE 5.0 100.6 20.1 100.6 80 9-Start Cement Slurry Pause 0.0 0.0 5.0 0.0 80 18-Drop Top Plug Mud 8.5 410.0 48.2 410.0 80 49-Rig Pumps To Displace Mud 3.0 32.8 10.9 442.8 80 49-Rig Pumps To Displace Total 01:43 613.4 bbl hr:mn End Job: Bump Top Plug, Bleed-off PSI, Check floats Dynamic Security Checks : Frac 293 psi at 2357.0 ft Pore 135 psi at 2357.0 ft Collapse 4501 psi at 6048.0 ft Burst 6554 psi at 0.0 ft Page 7 oil1-01.cfw;08-05-2010; LoadCase 9-5/8 Intermediate Casing(a);Version wcs-cem480_14 Client : Eni Petroleum Well : 0111-01 SGhlumherger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) Temperature Results BHCT 83 degF Simulated Max HCT 86 degF Simulated BHCT 63 degF Max HCT Depth 6128.0 ft CT at TOC 63 degF Max HCT Time 00:00:00 hr:mn:sc Static temperatures: At Time (hr:mn) (hr:mn) Geo.Temp. Top of Cement (degF) (degF) 1 75 degF Bottom Hole (degF) (degF) 86 degF o __.__ Acquired Pressure I Cale.WHP Q. ' ■ 1 I i �� .r..._ ... __-_..�........ oI 0 20 40 60 80 100 120 Time (min) Fluids at 6128 ft c°' Y —Acquired Q Out 1- -- , . 1— ix o ti._ L7 . 1 r t t t 0 20 40 60 80 100 120 Time (min) Page 8 oi11-01.cfw;08-05-2010; LoadCase 9-5/8 Intermediate Casing(a);Version wcs-cem460_14 Client : Eni Petroleum Well : 0111-01 Schlmulirger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) * CemCADE Client : Eni Petroleum Well :0111-01 String :9-5/8"Intermediate Casing District : Prudhoe Bay,Alaska Country : USA Depth= 6128 ft o Depth= 2357 ft Frac -Pore --Fore -Hydrostatic I -Hydrostatic V C -Dynanic -Dynanic r o N ol in 1 0 0) 6 o E 2 to m c 0 . N rn..-- °' 2 I >i a•7- /^ t1 o o. U Q LI V Q r g m O d co m Lo U it o i 0 0 R co rJ cp 0 40 80 120 0 30 60 90 120 Time(min) Time(min) o Total Depth = 6128.0 ft Top of Cement=4769.0 ft *Mark of Schlumberger SIIIIl eriPr Page 9 oil1-01.cfw:08-05-2010; LoadCase 9-5/8 Intermediate Casing la);Version wcs-cem460_14 Client : Eni Petroleum Well : 0111-01 Schlumbergcr String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) Section 4: centralizer placement Top of centralization :4769.0 ft Bottom Cent. MD :6108.0 ft Casing Shoe :6128.0 ft NB of Cent. Used :34 NB of Floating Cent. :0 Centralizer Placement Bottom MD Nbr. Cent.I Cent. Name Code Min.STO @ Depth (ft) Joint (%) (ft) 6128.0 34 1/1 NW-TR-9 5/8-6-TR 3A W090 65.9 4788.0 Centralizer Description Centralizer Tests Cent. Name Code Casing Max. Min.OD Rigid Origin Hole Size Running Restoring OD OD (in) (in) Force Force (in) (in) (Ibf) (Ibf) NW-TR-9 5/8-6-TR W090 9 5/8 12.850 11.591 No Hannover 11.625 775.59 5626.97 3A (1)-Centralizer performance data is based on tests by WEATHERFORD as per the current API 10D specifications Running Force Calculations: Travelling Block Weight :33 ton Friction Factor Centralizer/Formation :0.3 Total Drag Force :16 ton Hook load Down Stroke :91 ton Hook load Up Stroke :122 ton ft °4 0 7n 40 60 80 100 I Between Cent. I 4 +At C ---f I 1 Cent. ! I1_ ' i ii 1 g- i ■I NMI ■! NC-C.. ..... i. - a':::: MIlli i a . � ;� , IIriIII:1IIH 111m1 ► 1n __ Pipe Standoff Page 10 oil 1-01.ciw;08-05-2010; LoadCase 9-5/8 Intermediate Casing lal;Version wcs-cem460_14 Client : Eni Petroleum Well : 0111-01 SCOI0161011 String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) * CemCADE Client : Eni Petroleum Well :0111-01 String :9-5/8"Intermediate Casing District : Prudhoe Bay,Alaska Country : USA ft ton 0 25 50 75 100 125 0 —Hooldoad Up \ _ \ —— Hooldoad Down \ \ - - • Weight -N. \ -- — Rag Force \ 1 \ •'. I \ • I • 0 \ \ d a 0 \\ \ N \ v I \ E I \ m m 3 \ \ 1 \ N i \ •\ \ - \ \ g' O a O_ \ \ m 0 \ \ • S 1.0 - \ 1 1 . EE \ / m 5g) O o r O Uc q� d 0 Running Forces _o Friction Factor=0.3 Total Depth = 6128.0 ft Top of Cement= 4769.0 ft *Mark of Schlumberger SChIImberPr Page 11 oil 1-01 cfw:08-05-2010: LoadCase 9-5/8 Intermediate Casing(a);Version wcs-cem480_14 Client : Eni Petroleum Well : 0111-01 SO10111161 String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) Section 5: WELLCLEAN II Simulator ft % 2 I 75 100 —Std Betw.Cent. - —Cement Coverage o - I .� o 1111 s o- ■. ■■MOM•a.. N - _ 1111- _ • ■•■i_ O rte O _ __i �lal�lf•I-_ 1 1.11111 11111111�® l�lii1111 O - I ■..■.. 1 o 1 _ ■t 0 Cement Coverage Fluids Concentrations Risk Mud on the Wall 4800 4800 4800 — 4 800 5000 5000 5000 . 5000 5200 5200 5200 lto 5200 — 5400 5400 -- s 5400-4 5400 i n Ti a 5600 5606 ,a o° 5600 5600 n` 5800 5800 5800 5800 $000 _ 6000 6000 6004 z I IIIII Mud I I High Low DeepCRETE I 1 Medium = None I I MUDPUSH II Page 12 0(11-01.cfw;08-05-2010; LoadCase 9-5/8 Intermediate Casing(a);Version wcs-cem460_14 it Client : Eni Petroleum Well : 0111-01 ScIberger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) Section 6: fluid description Mud DESIGN Fluid No: 1 Density :9.50 lb/gal Rheo. Model : BINGHAM Pv :20.038 cP At temp. :80 degF Ty :20.59 Ibf/100ft2 Gel Strength :(Ibf/100ft2) MUD Mud Type :WBM Job volume :442.8 bbl Water Type : Fresh VOLUME FRACTION Solids :4.0% Oil :96.0% Water :0.0% MUDPUSH 11 DESIGN Fluid No:2 Density : 10.50 lb/gal Rheo. Model : BINGHAM Pv :36.000 cP At temp. :80 degF Ty :20.00 Ibf/100ft2 Gel Strength : (Ibf/100ft2) Job volume :70.0 bbl DeepCRETE DESIGN Fluid No:7 Density : 12.50 lb/gal Rheo. Model : HERSCHEL_B. k :6.48E-3 Ibf.s^n/ft2 At temp. :80 degF n :0.848 r'G5 • Ty :7.241bf/100ft2 V Gel Strength :40.56 lbf/100ft2 DESIGN BLEND SLURRY Name : D972 Mix Fluid :5.181 gal/sk ✓ Job volume : 100.6 bbl Dry Density : 119.32 lb/ft3 Yield : 1.54 ft3/sk Quantity :367.88 sk Sack Weight : 100 lb Solid Fraction :54.9% BASE FLUID Type : Fresh water Density :8.32 lb/gal Base Fluid :5.121 gal/sk Additives Code Conc. Function D167 0.250%BWOB Fluid loss D046 0.129%BWOB Antifoam D185 0.040 gal/sk blend Dispers.LT D153 0.100%BWOC Antisettling D177 0.010 gal/sk blend Retarder Page 13 oi11-01 cfw;08-05-2010; LoadCase 9-5/8 Intermediate Casing(a),Version wcs-cem460_14 Client : Eni Petroleum Well : 0111-01 Schi krger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) Section 7: operator summary Start Job: Circulate Two Hole Volumes, Safety Meeting,Test Surface Equipment Operator Pumping Schedule Name Flow Rate Volume Stage Time Cum Vol Comments (bbl/min) (bbl) (min) (bbl) MUDPUSH II 5.0 70.0 14.0 70.0 7-Start Pumping Spacer Pause 0.0 0.0 5.0 0.0 4-Drop Bottom Plug DeepCRETE 5.0 100.6 20.1 100.6 9-Start Cement Slurry Pause 0.0 0.0 5.0 0.0 18-Drop Top Plug Mud 8.5 410.0 48.2 410.0 49-Rig Pumps To Displace Mud 3.0 32.8 10.9 442.8 49-Rig Pumps To Displace Total Pumping Time : 01:43 hr:mn End Job: Bump Top Plug, Bleed-off PSI, Check floats Mix Water Requirements : Fresh water 110 bbl MIXING PREPARATION MUDPUSH II Volume:70.0 bbl Density: 10.50 lb/gal Code Quantity Design Fresh water 63.747 bbl D182 382.481 lb 6.000 lb/bbl of base fluid D046 12.749 lb 0.200 lb/bbl of base fluid D031 8198.954 lb 117.13 lb/bbl of spacer DeepCRETE Volume: 103.6 bbl Density : 12.50 lb/gal Yield : 1.54 ft3/sk Dry Phase Liquid Phase Blend: 38053 lb Design Mix Water 46.7 bbl 10.0 bbl LAS Design D972 37884.613 lb Fresh water 46.197 bbl 9.885 bbl D167 94.712 lb 0.250%BWOB D185 15.154 gal 3.243 gal 0.040 gal/sk blend D153 24.443 lb 0.100%BWOB D177 3.788 gal 0.811 gal 0.010 gal/sk blend Page 14 oi11-01.cfw,08-05-2010; LoadCase 9-5/8 Intermediate Casing(a);Version wcs-cem460_14 Client : Eni Petroleum Well : 0111-01 Seib Mier String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) CemCADE Client : Eni Petroleum Well :0111-01 String :9-5/8" Intermediate Casing District : Prudhoe Bay,Alaska Country : USA Annulus ID:9.625 in-OD: 12.250 in o NUDPUSHII -Mid -DeepCRErE U) tD O O O < O o � d Y N 3 � o V1 N o_ U d p 3.9 4.2 4.5 4.8 5.1 5.4 5.7 6.0 6.3 6.6 6.9 7.2 7.5 7.8 8.1 Flow Rate (bbl/min) .o ■Mud Bingham:PV=20.038 cP Ty=20.59 Ibf/100ft2 MUDPUSH II Bingham PV=36.000 cP Ty=20.00 Ibf/100ft2 DeepCREE Herschel:k =6.48E-3 Ibf.s^n/ft2 n =0.848 Ty=7.24 Ibf/100ft2 it *Mark of Schlumberger r Page 15 oil1-01.cfw;08-05-2010; LoadCase 9-5/8 Intermediate Casing WI;Version wcs-cem460_14 S P E O IDENTIFICATION CODE PAG 206 OF 338 ENI S.p.A. En! E&P Division REVISION STAP-P-1-M-6140 0 11 1 1 1 1 1 1 15. LEAK OFF TEST PROCEDURE A Leak-Off Test (LOT) will be performed On Wild-Cat wells at each casing shoe after setting the surface casing. LOTs are also recommended to be carried out on both appraisal and development wells. Leak Off Test and Formation Integrity Test (FIT), also termed the Limit Test, are for formation strength pressure tests made just below the casing seat prior to drilling ahead. These tests are carried out to: • Investigate the cement seal around the casing shoe which should be at least as high as the predicted fracture pressure for the area. • Investigate the weilbore capability to withstand pressures below the casing shoe in order to allow proper well planning with regard to the setting depth of the next casing, mud weights and alternatives during well control operations. • Collect regional information on formation strengths and stress magnitude for different applications including optimisation of future well planning, hole stability analysis and modelling, reservoir application. Prior to a test, a decision should be made to either increase the pressure until leak off occurs (as in the LOT) or to stop at a predetermined pressure for a (FIT). It should be noted that: • FIT does not obtain information on stress magnitude. • A LOT is designed and should be performed to determine, in a better way, the desired data without breaking down the formation. When a Formation Integrity Test is required, the maximum pumping pressure is often expressed in terms of'Equivalent Mud Weight' (EMW): Imperial units EMW= +MW 0.052 x TVD where: P = Pumping Pressure(psi) TVD = True Vertical Depth (ft) MW = Actual Mud Weight(PPG) Metric units EMW = Px10 + MW TVD where: P = Pumping Pressure (kg/cm2) TVD = True Vertical Depth (m) MW = Actual Mud Weight(kg/I). S P E O IDENTIFICATION CODE PAG 207 OF 338 ENI S.p.A. E11l E&P Division REVISION STAP-P-1-M-6140 0 11 1 1 1 1 1 LOTts or FITs can be carried out in any open hole section and at any time while drilling the hole, even if it is customary to have it performed some metres (6-15 metres) below the casing. For instance,the casing seat can be in a shale and the first sand formation may be encountered several hundred feet deeper. This will certainly be more permeable than the shale, and a test can be performed to ascertain the maximum pressure this sand can hold. If it is lower than the shale just below the casing seat, this sand becomes the limiting factor. Note Information obtained from leak-off tests in straight holes is not applicable to deviated holes in the same field and vice versa. 15.1 TEST PROCEDURE Prior to performing a formation strength test, prepare a sheet of graph paper to record pressure, versus cumulative mud volume. 1) Drill out the float equipment, clean the rat hole and drill 5m of new hole. 2) Circulate a mud quantity equal to the internal string volume plus the new hole plus 50m internal casing volumes. This mud shall be cleaned and conditioned to the density and filtrate as indicated in the Mud Programme to be used for the next drilling phase. 3) Pull the bit back into the casing shoe. 4) Rig up the cementing unit to the drill pipe. The unit shall be equipped with high precision, low pressure gauges. The range of the pressure gauge shall be selected based on the actual mud weight and the estimated (LOT)or predetermined (FIT) pressure. A pressure recorder should be used during the test. The use of the rig pumps for making these tests is unsuitable. 5) Fill and test the lines with mud. 6) Break circulation with the cementing unit to make sure that the bit nozzles are clear. Stop pumping when circulation is established. 7) Close the top pipe rams or the annular. 8) In surface well head both flanged and multistage wellheads, open the annulus of the previous casings. In sub sea well head pay attention to not excide the burst pressure of the previous casing. 9) Pump slowly and in continuous way, until pressure builds up to approximately half the anticipated maximum surface pressure. 10) Once pressure is established, pump uniform volumes of mud and wait for the time required for the pressure to stabilise. The flow rate range is from 1/8 bbl/min (20 I/min) up to a maximum of 1 bbl/min (160 I/min), however values of 0.25 bbl (121/4" and smaller holes) or 0.50 bbl (171/2" hole) are commonly used. 11) Note the cumulative mud volume pumped, the final pumping and final static pressure. 12) Repeat steps (9) and (10) above and plot pressure versus cumulative mud volume for each increment of pumped volume. S P E O IDENTIFICATION CODE PAG 208 OF 338 ENI S.p.A. E&P Division REVISION STAP-P-1-M-6140 0 11 I ! I I 13) Continue this procedure until: • Two or three points on the plot are reached where the pressure deviates and falls below the approximate straight line (or if the pressure does not increase with the injected volume). The point on the plot where the curve begins to bend away from the straight line is called Leak Off Point (Refer to Figure 15-1) • Or the predetermined test pressure is reached. 14) Stop pumping, shut in the well, record and plot pressure versus time until stabilisation (usually it takes 15-20min). In the early stage (2-3min) one value every 15-30sec should be collected while for the remaining a value of pressure every 30- 60sec may be sufficient. The use of PACR or an equivalent device, if available, is preferred. 15) Bleed off the pressure and record the quantity of fluid returned into the cementing unit. Compare it to the volume used for the test to obtain the amount of fluid lost to the formation. 16) Open the BOP and calculate the formation strength in terms of 'Equivalent Mud Weight' using the lowest between leak off point pressure and stabilised pressure. 17) Collect the data recorded during the test in a data sheet together with the following information: borehole diameter, depth of test, depth and type of the last casing, mud density, plastic viscosity, filtrate and gels (refer to the example on the next page). Note: The LOT pressure doesn't exceed the pressure which the casing was tested. Note: When a good zonal isolation behind the casing is imperative, the Leak- off test should be carried out with a retrievable packer to avoid pressurising the casing which may cause possible permanent damage to the cement bond by the creation of micro annuli in the cement. Note: The pumping rate should be kept within the limits described in step 9). If the rate is too low, filtration losses will mask any leakage loss, or, if the rate is too high the formation may suddenly break and the leak off pressure will not be determined. Also,the longer the open hole section, the higher should be the injection rate. If the initial pumping rate is not sufficient, the well should be depressurized and the test restarted with a higher rate. Note: If a float valve is used in the drilling string, the test can not be carried out by pumping down the drill pipe. In this case rig up the cementing unit to the choke or kill line, fill and test the lines against the fail-safe and establish circulation through the riser. Close the BOP and perform the formation strength test pumping down the annulus. S P E O IDENTIFICATION CODE PAC 209 OF 338 •ENI S.p.A. �P1� E8tP Division REVISION STAP-P-1-M-6140 0 1 LEAK-OFF TEST REPORT Report N° Date: - WELL N.aME: WELL CODE: CONTRACTOR: RIG NCME'. RIG CODE: Open hole depth(m): 825 Mud Type: FWGELS Rigt}pe: J.UPs Hole Ctameter(in): 12"1/4 Weight(Kgd): 1.3 R.K.B.eleiahon(m): 28 Last Csg.Shoe(m): 797 Marsh 1Ascosity(sec/Ot): 44 Water Depth(m): 24 Csg.diameter On): 13"3B P.V.(cps): 19 Pumps: 12-P-160 Grade: J.55 Y P.(1b1100 50): 5 Liners(in): 6.5" Weight 0b/t): 61 GelsQb/100'ID.: __ _ 2/8 Flow Rate(bpi): 0.25 Max.Burst pres(psi): 3103 W.L(cc/30 min): 10.5 Litholog y Shale Expected EMW 1.68 Kg/cm2/1 0 rn Time Volume Pressure Time Volume Pressure Time Voume Pressure (min) (bid) !Psi) (min) (bbl) (Psi) (min) (bbl) (Psi) 1 025 50 8 2 400 16 2 435 2 060 100 95 2 480 3 0.75 200 t0 2 470 4 100 300 10.5 2 463 5 125 400 11 2 455 6 150 500 11.5 2 450 7 1.75 570 12 2 445 8 200 600 13---- 2 440 - -- --- 8 200 550 14 2 437 85 200 505 15 2 435 _ Nct e. Pumped with a constant tow rate of(bbl): Volume pumped(bbl): Volume returned(bbl): (psi) 1000 900 800 stop pump P r 700 e 600 ` 'hut in curve S 500 / . U 400 r 18 minutes e 300 - 200 - - - 100 . 0 . . . . . . . . . . 0 0,25 0,5 0,75 1 1,25 1,5 1,75 1 2 3 4 5 6 7 8 9 10 11 12 Cumulative Volume(bbD Time mins RESULTS: (Press.,,,,n+Press.Lo.))(100 epth=[(1.3 x 797 110)+(430 x 0.07)]x 10 1 797=1.68(Kg/cm2I10 m) Note: I Company Representati+.e Figure 15-1 - Leak-Off Test Report 0 ■ REV DATE BY CK APP DESCRIPTION REV DATE BY CK APP DESCRIPTION 1 12/16/08 MRT AJR Add New Well Conductors 4-24 2 12/23/08 JFC JMS Add New Well Conductor OP26 Oliktok OLIKTOK 5 14 Point INTAKE 0 vilt MODULE DOCK �\ OPP THIS Sb 1 . v. 0 P /5 SURVEY _O N 4---- r DS-3R% ! ,..--11)8 �9... 0 DEW U E / SITE STP , •OIJKTOK'P01Ni MODULES I � NOC STAGING AREA.. Ti 3N R9E DSS-3Q� 18 1 U , 'O 15 SCALE: . 1" = 150' ; DS-30 19 (-2-6,i i 21 �, 2, STP P AD VICINITY MAP 0,0 SCALE: 1" = 1 Mile O°°-0 \ \"0° 6 - \g00 'O N3 0 0.0 --*0+ \ `'v. 00-0 �° Zi \\:„\\ � ;pOO �q � j � �000°-0.O '0 . S G� '\ 0� �O v �O-0 t �O�� \ 01 -13 0. \ / \ O'7i ` OLIKTOK \ POINT PAD 0� \ N..3s \ o \\ 0 o u / \ \ SEE SHEET 3 FOR NOTES \ \ / l U Existing Conductor ' LOUNSBURY � & ASSOCIATES, INC. • Conductor Asbuilt this survey / SURVEYORS ENGINEERS PLANNERS I AREA: MODULE: UNIT: ^ - En P&limIIGum OLIKTOK CONDUCTOR ASBUILT LOCATIONS CAD LK68001 10/9/08 DRAWING NO: NSK 6.80—di PART: 1 OF 3 REV: 2 REV DATE BY CK APP DESCRIPTION REV DATE BY CK APP DESCRIPTION 1 12/16/08 MRT AJR Add New Well Conductors 4-24 2 12/23/08 JFC 1 JMS Add New Well Conductor OP26 PROTRACTED SECTION 5, T. 13 N., R. 9 E., UMIAT MERIDIAN AK STATE PLANE(NAD83) LATITUDE(N) LONGITUDE(W) SEC. LINE PAD 0.G. WELL NO. 'y' 'X' NAD83 NAD83 OFFSET ELEV. ELEV. F.N.L. F.E.L. OP-11 6,036,332.70 1,656,791.89 70°30'39.015" 149°51'57.587" 2,052 1,519 12.1 4.0 OP-12 6,036,328.85 1,656,784.83 70°30'38.977" 149°51'57.795" 2,056 1,526 12.2 4.0 0P03-P05 6,036,325.10 1,656,777.76 70°30'38.940" 149°51'58.004" 2,059 1,533 12.2 4.0 0PO4-P07 6,036,321.43 1,656,770.69 70°30'38.904" 149°51'58.212" 2,063 1,541 12.2 3.8 OP05 6,036,317.71 1,656,763.67 70°30'38.868" 149°51'58.419" 2,067 1,548 12.2 3.7 OP06 6,036,313.96 1,656,756.55 70°30'38.831" 149°51'58.629" 2,070 1,555 12.2 3.6 OP07 6,036,306.41 1,656,742.45 70°30'38.757" 149°51'59.045" 2,078 1,569 12.2 3.5 OP08 6,036,302.66 1,656,735.36 70°30'38.720" 149°51'59.254" 2,082 1,576 12.2 3.5 OP09 6,036,298.90 1,656,728.32 70°30'38.683" 149°51'59.462" 2,085 1,583 12.2 3.5 OP10 6,036,295.16 1,656,721.26 70°30'38.647" 149°51'59.670" 2,089 1,590 12.2 3.7 OP11 6,036,291.38 1,656,714.21 70°30'38.610" 149°51'59.878" 2,093 1,597 12.2 3.8 . OP12 6,036,287.63 1,656,707.14 70°30'38.573" 149°52'00.086" 2,097 1,604 12.2 4.0 OP13 6,036,276.37 1,656,685.97 70°30'38.463" 149°52'00.711" 2,108 1,626 12.2 3.6 OP14 6,036,272.66 1,656,678.89 70°30'38.426" 149°52'00.920" 2,112 1,633 12.2 3.5 OP15 6,036,268.88 1,656,671.79 70°30'38.389" 149°52'01.129" 2,115 1,640 12.2 3.4 OP16 6,036,265.11 1,656,664.75 70°30'38.353" 149°52'01.337" 2,119 1,647 12.2 3.3 OP17 6,036,261.36 1,656,657.70 70°30'38.316" 149°52'01.545" 2,123 1,654 12.2 3.2 OP18 6,036,257.62 1,656,650.62 70°30'38.279" 149°52'01.753" 2,127 1,681 12.2 3.1 OP19 6,036,250.09 1,656,636.50 70°30'38.205" 149°52'02.170" 2,134 1,675 12.2 2.5 OP20 6,036,246.31 1,656,629.41 70°30'38.168" 149°52'02.379" 2,138 1,682 12.2 2.2 OP21 6,036,242.57 1,656,622.39 70°30'38.132" 149°52'02.586" 2,141 1,689 12.2 1.9 OP22 6,036,238.82 1,656,615.39 70°30'38.095" 149°52'02.793" 2,145 1,696 12.2 1.7 OP23 6,036,235.05 1,656,608.27 70°30'38.058" 149°52'03.003" 2,149 1,703 12.2 1.5 OP24 6,036,231.36 1,656,601.27 70°30'38.022" 149°52'03.209" 2,153 1,710 12.2 1.3 DISPOSAL WELLS AK STATE PLANE(NAD83) LAT1TUDE(N) LONGITUDE(W) SEC. LINE PAD 0.G. WELL NO. 'y' 'x NAD83 NAD83 OFFSET ELEV. ELEV. F.N.L. F.E.L. OP25 6,036,004.35 1,656,510.91 70°30'35.791" 149°52'05.885" 2,380 1,802 12.2 -2.7 OP26 6,036,012.10 1,656,525.47 70°30'35.867" 149°52'05.456" 2,372 1,787 12.2 -2.7 LOUNSBURY & ASSOCIATES, INC. SURVEYORS ENGINEERS PLANNERS AREA: MODULE: UNIT: •l - Eno Petrollkun IKTCONDUCTOR IN ° WELL . 0 ASBUILT LOCATIONS CADD FILE NO. DRAWING NO: PART: REV: LK680D1 10/9/08 _ NSK 6.80-di 2 OF 3 2 0 • REV DATE BY CK APP DESCRIPTION REV DATE BY CK APP DESCRIPTION 1 12/16/08 MRT AJR Add New Well Conductos 4-24 2 12/23/08 JFC JMS Add New Well Conductor OP26 NOTES 1. COORDINATES SHOWN ARE A.S.P. ZONE 4, NAD 83. DISTANCES SHOWN ARE TRUE HORIZONTAL DISTANCES. 2. GEODETIC COORDINATES SHOWN ARE NAD 83. 3. BASIS OF LOCATIONS ARE DERIVED FROM OPUS SOLUTIONS. 4. CONDUCTORS ARE LOCATED WITHIN PROTRACTED SECTION 5, TOWNSHIP 13 NORTH, RANGE 9 EAST, UMIAT MERIDIAN. 5. ALL ELEVATIONS SHOWN ARE B.P.M.S.L. DATUM. 6. SEE LOUNSBURY DOCUMENT L-2539 FOR NAD27 INFORMATION. SURVEYOR'S CERTIFICATE ■ rte • • ��'' 1I . . h 1ll I HEREBY CERTIFY THAT I AM PROPERLY • / / REGISTERED AND LICENSED TO PRACTICE 0 II.. „ A, 0 LAND SURVEYING IN THE STATE OF 0 c 'M J. ROOKUS o r ALASKA AND THAT THIS PLAT REPRESENTS • : j_�r• A SURVEY DONE BY ME OR UNDER MY #�♦sT Ls-803 ,,,,pp • --4'fi DIMENSIONS AND OTHER DETAILS ARE ♦,o+ pR0 23 1 PN4i�•• CORRECT AS OF DECEMBER 23, 2008. ,,"ltI"�� 0 LOUNSBURY & ASSOCIATES, INC. SURVEYORS ENGINEERS PLANNERS AREA: MODULE: UNIT: ii:-da NI t O D Ern f iroIIei WELL CONDUCTOR ASBUILT LOCATIONS CADD FILE NO. DRAWING NO: PART: REV: LK680D1 10/9/08 NSK 6.80—d1 3 OF 3 2 Davies, Stephen F (DOA) From: Davies, Stephen F (DOA) Sent: Tuesday, August 10, 2010 9:56 AM To: 'Province Robert' Subject: Nikaitchuq 0111-01: Spacing Exception Needed Robert, Until pool rules are approved for the Nikaitchuq development, statewide spacing rules apply for all wells. 0111-01 will be the third well open to the OA sand in the NE 1/4 of Section 31,T14N, R9E (also open: OP12-01 and Oliktok Pt 1-2), and 0111-01 will also be the third well open to the OA sand in the NW 1/4 of Section 32,T14N, R9E (also open: OP12-01 and OP08-04). So, an exception to the spacing requirements of 20 AAC 25.055(a)(3)is needed for 0111-01. Thanks, Steve Davies AOGCC 793-1224 1 0 O 1 0 00o M ... 0 0 N • 0 O 0 N- . Ce o L L W V Q O _— O Off' • -r r, M O 0 CI N r o CO 1 ED C O o �- 0. I U v X • c O O W O L O CD NNIP8- O LO y- M CF N , Q Q co C . O W o O O O O O O O O O O O O NI- O O O O O 0 lf, O CO CO LO LO LO . AD 4 pL.DI se-lz-t0 2/6 -/.66 00 0o O °o a 00 00 00 ' N coo N- 00 C 8 0 coo a 0 1- I I I U a I I 1 1,... o I o v O I� - o o co ° i M o- a a "r` o a o a o 0 a E E I Oro O a O v o O m CI CL u \ 0 0 CL o � 0 0 co o co a F� a+ rci • ° cn a▪= p S . O O f „ a M r, 0 z a s CO 0 • •Ca o •o ., °6/e'e b cF O �o �c a g - `d<<e •� °7 ° -tea .J Z69 q7 �b9' N7 r Oq f t?tr • .-- O ' O•B MM ° C '4F � �O e- 6 o N - p /0 o L LL 11 N O p s m N m N N w a aE _� o v O V y• m a, •�f _a fbm a • - r-+ C b '$ �ef • • Y ..9f,, Y°a ' O eo n n- E O O a l O Dr Y O C r e N c cr . r t n oll Ire. �9DF O OY p F g _ Q I I t w O co bad, /C/C:5 N c.) \1 •Y i s ill �^� a 7�`�▪ A • O ba4, �F U C Z s f69f 1 56b 1z3 0 �- E d £� 3 O - p p s o • ''.lam N w 0 q v LL �3 O �f d � -p V > O v E v tv°� > 0 R (r C O r8 0 fre mgyi • ,0 It 6:,CO 3N r ((wjj `r..o F N O > SO I /- /L •— _ �� F c h 8N r O 9F N �J‘';�. F d a ` e 0 • 14\ .— • b Q \ $m a ` le, FDf c o s qze A 9• re o O ID — O �eF'9F C 0 • r `•O Y �� , \ F O cQ Cl a .,• °rF S (9 a ,; �. E 0 Q d$ o C o p `�` a I • 0 � I- s e �°, a 0- E ° H o -F 0 O v F Y e 00 > .- c o °o o - Q � - o `t SA 1 4.4(75 -§ i 1 1 O 00 0 0 0 0 0 0 O C.CI CO °coo Lc, 0v el «< N (4)0001.:0-10 1, =eteos g >>> Schlumherger 0111-01 (P4) 1/4 Mile Scan Analysis Method: 3D Least Distance Distance Unit: ft Depth Interval: Every 25.00(ft)Measured Depth Azimuth Unit: deg Step-down Trajectory: Reference Trajectory TC Azimuth Reference: North Analysis Date-2411r Time: August 11,2010-12:27 North Reference: True Analysis Machine: DELAPP-M4400 Client ENI Database I Project: localhostldrifing-proil Version/Patch: 2009.1.745.0 NOTE:Measured Depth is referenced to individual borehole elevation. TVD,NS,EW are referenced to the reference trajectory's wellhead location and borehole elevation. A minimum of 0.300 m is always included for borehole diameters. Absolute minimum indicated. Results filtered:Depth 3600.00 ft en TVD<=3700.00 ftDepth 3600.00 ft<=TVD<=3700.00 ft,Ct-Ct separation<=1320.00 ft Reference Trajectory Summary Field: Nikaitchuq Well: 0/11-01 Structure: Olildok Paint Borehole: OP11-101 Slot: OH/ Trajectory. 0111-01(P4) Client: ENI Type: Dot Plan Structure MAS: 4.159(ft) Coordinate System: NAD27 Alaska State Plane,Zone 04,US Feet North Reference: True Grid Convergence Angle: 0.12869420° Grid Scale Factor: 0.99990032 Magnetic Declination: 21.510° Magnetic Declination Date: August 15,2010 Magnetic Model: BGGM 2010 Reference Point: Northlno Eastinq Elevation Structure Unc.ltsd( Slot Unc.ltsd) 6036539.390(ftUS) 516682.790(11US) 52.200(ft)MSL 0.000(ft) 0.000(ft) Tralectory Error Model:ISCWSAO 3-D95.000%Confidence 2.7955 sigma Surveying Prod: MD Fro (ftl m MD To(ft) EOU Freg(ft) Survey Tool Type NOW Diameter(In) Borehole/Survey 0.000 40.000 1/100.000 SIB_GYRO-MWD-Depth Only-No Global 16.000 OP11-101/0111-01(P4) 40.000 1200.000 1/100.000 SLB_GYRO-MWD-No Global 16.000 OP11-101/0111-01(P4) 1200.000 2356.630 1/100.000 SLB_MWD+GMAG-No Global 16.000 OP11-101/0111.01(P4) 2356.630 6128.362 1/100.000 SLB MWD+GMAG-No Global 12.250 OP11-101/0111-01(P4) 6128.362 10521.353 1/100.000 SLB_MWD+GMAG-No Global 8.500 OP11-101/0111-01(P4) Offset Trajectory Summary Offset Selection Summary Wells Selected:3 Boreholes Selected:4 Definitive Surveys Selected:3 Non-Def Surveys Selected:0 Definitive Plans Selected:/ Non-Def Plans Selected:0 Total Trajectories:4 Trajectory Borehole Well Type OP1O-P09(P2) OP10-P09 OP10-P09 Def Plan OP12-01 OP12-01 OP12-01 Def Survey OP08-04PB1 OP08-04PB1 OP08-04 Der Survey OP08-04 OP08-04 OP08-04 Def Survey Drilling Office 2009.1.745.0 Nikaitchuq\Oliktok Point\0111-01\OP11-101\0111-01(P4) 8/11/2010 12:39 PM Page 1 of 5 Field: Nikallo'wq Well: OP/04P09 Structure: (Wok Point Borehole: OP/0?09 Slot: OP10 Trajectory. OP10-P09(P2) Client: ENI Type: Del Plan Structure MAS: 4.159(1y Coordinate System: NAD27 Alaska State Plane,Zone 04,US Feet North Reference: True Grid Convergence Angle: 0.12874865° Grid Scale Factor. 0.99990032 Magnetic Declination: 21.478° Magnetic Declination Date: November 11,2010 Magnetic Model: BGGM 2009 Reference Point: Nadu n Bp faiaLkm Structure Unc-ttsdj Slot Unc.11sd( 6036543.170(SUS) 516689.840(SUS) 52.200(It)MSL 0.000(5) 0.000(11) Reference Cylinder North MD Reference TVD Reference NS Reference EWI Offset MD Offset TVD I Offset NS I Offset EW Azim Ct-Ct Distance (S) (9) (ft) (9) (9) (9) (9) (ft) (°) (ft) Absolute minimum indicated. Results filtered:Depth 3600.00 ft<=TVD<=3700.0011 Results filtered:Ct-Ct separation<=1320.0011 Resutts highlighted:Ct-Ct separation<=1320.00 ft 10150.00 3685.68 6818.04 -4000.19 10699.62 3684.78 8039.37 -3506.82 35.81 1317.22 10175.00 3684.94 6832.50 -4020.57 10723.83 3686.51 8048.41 -3529.20 35.75 1311.44 1017868 3684.82 683462 -4023.58 10727-39 3686.74 8049.74 -3532.50 35.74 131060 10200.00 3684.09 6846.91 -4040.99 10748.07 3688.03 8057.48 -3551.64 35.83 1305.74 10225.00 3683.23 6861.31 -4061.41 1077236 3689.35 8066.56 -3574.12 35.93 1300.05 10250.00 3682.37 6875.71 -4081.83 1079668 3690.47 8075.66 -3596.65 36.02 1294.36 10275.00 3681.51 6890.11 -410224 10821.03 3691.38 8084.78 -3619.21 36.11 1288.67 10300.00 3680.65 6904.51 -412266 10845.41 369209 8093.91 -3641.81 36.18 1282.98 10325.00 3679.79 6918.91 -4143.08 10869.82 3692.59 8103.05 -3664.43 36.24 127729 10350.00 3678.93 6933.31 -4163.50 10894.25 3692.88 8112.20 -3687.08 36.30 1271.60 10375.00 3878.08 6947.71 -4183.92 10918.69 3692.96 8121.36 -3709.75 36.35 1265.90 10400.00 3677.22 696211 -4204.33 10943.15 3692.83 8130.52 -3732.42 36.38 1260.21 10425.00 3676.36 6976.51 -4224.75 10967.62 3692.50 8139.68 -3755.10 36.41 1254.51 10450.00 3675.50 6990.91 -4245.17 1099021 3692.10 8148.15 -3776.04 36.43 1248.82 10475.00 3674.64 7005.31 -4265.59 11007.23 3691.80 8154.59 -3791.80 36.45 1243.23 10500_00 3673.78 7019.71 -4286.01 1102670 3691.43 8162.07 -3809.77 36.47 1237.78 10521.35 3673.05 7032.01 -4303.45 11047.54 3691.04 8170.09 -3829.00 36.49 1233.15 End of results Drilling Office 2009.1.745.0 Nikadchuq\Oliktok Point\0111-01\OP11-101\0111-01(P4) 8/11/2010 12:39 PM Page 2 of 5 Field: Nikaitchuq Well: 0P12-01 Structure: O660Ok Point Borehole: OP12-01 Slot: OP12 Trajectory: OP12-01 Client: ENI Type: Doi Survey Structure MAS: 4.159(Ip Coordinate System: NAD27 Alaska State Plane,Zone 04,US Feet North Reference: True Grid Convergence Angle: 0.12863958° Grid Scale Factor. 0.99990032 Magnetic Declination: 21.535° Magnetic Declination Date: July 28,2010 Magnetic Model: BGGM 2010 Reference Point Northing &afller gievation Structure Unc.11ad( Slot Uncjlad( 6036535.640(ftUS) 516675.720(SUS) 54.580(ft)MSL 0.000(ft) 0.000(ft) Reference Cylinder North MD Reference ND Reference NS Reference EW Offset MD Offset NO Offset NS Offset EW Azim Ct-Ct Distance (ft) (ft) (ft) (ft) (ft) (II) (ft) (ft) (°) (ft) Absolute minimum indicated. Results filtered:Depth 3600.00 ft•=ND<_3700.00 ft Results filtered:Ct-Ct separation<-1320.00 ft Results highlighted:Ct-Ct separation<=1320.00 It 6125.00 3632.57 3942.35 -1329.27 5712.71 3630.22 3013.15 -2138.19 25192 1231.98 6148.46 3634.30 3964.91 -133549 5732.23 3631.16 3025.95 -2152.89 251.97 1244.91 6150.00 3634.41 3966.39 -1335.90 5733.51 3631.22 3026.79 -2153.85 251.99 1245.76 6173.62 3636.19 3989.13 -1342.03 5753.08 3632.14 3039.62 -2168.60 252.40 1258.89 6175.00 3636.30 3990.46 -1342.39 5754.22 3632.20 3040.37 -2169.46 25240 125966 6200.00 3638.23 4014.55 -1348.76 5777.95 3633.28 3055.93 -2187.33 252.46 127164 6225.00 3640.16 4038.65 -1355.14 5809.17 3634.51 3076.57 -221173 252.54 1287.50 6250.00 3642.10 4062.74 -1361.52 5840.70 3635.48 309761 -2234.20 25264 1301.19 6275.00 3644.03 4086.84 -1367.90 5870.30 3636.14 3117.53 -2256.08 252.74 1314.72 9400.00 3684.23 6370.14 -339867 8952.11 364794 5413.34 -4305.08 218.91 131947 9425.00 368422 6385.30 -3418.55 8976.95 364843 5430.41 -4323.12 218.88 131980 9450.00 368421 6400,45 -3438.44 9001.79 3648.90 5447.48 -4341.16 218.87 1313.13 9475.00 3684.19 6415.61 -3458.32 9025.13 3649.21 5463.52 -435112 218.86 1310.47 9500.00 368418 6430.77 -3478.20 9043.97 3649.44 5476.43 -4371.84 218.85 1307.89 9525.00 3684.17 6445.92 -3498.08 9062.83 3649.67 5489.28 -438964 218.84 1305.42 9550.00 368416 6461.08 -3517.96 9081.70 3649.91 5502.08 -4399.51 218.83 1303.07 9559.61 3684.15 6466.91 -3525.61 9088.97 3650.00 5506.98 -4404.86 218.83 1302.19 956341 3684.15 6469.21 -3528.63 9091.83 3650.03 5508.92 -4406.97 218.76 1301.85 957900 3684.16 6476.21 -3537.87 9100.59 3650.14 5514.82 -4413.44 218.55 1300.79 9600.00 368425 6491.19 -3557.88 912167 3650.40 5528.98 -4429.07 218.12 1298.45 9601.35 3684.26 6491.99 -3558.97 9123.35 365043 5530.10 -4430.31 218.09 1298.32 9625.00 3684.39 6506.08 -3577.96 9152.67 3650.77 5549.82 -4452.00 218.09 1295.96 9650.00 3684.53 6520.97 -3598.04 9183.63 3651.11 5570.76 -4474.81 218.09 129135 9675.00 3684.87 6535.86 -3618.12 9214.61 3651.42 5591.81 -4497.53 218.08 1290.62 9700.00 3684.81 6550.76 -3638.20 9245.91 3651.67 5613.20 -4520.38 218.09 1287.77 9725.00 3684.95 6565.65 -3658.28 9277.18 3651.85 5634.68 -454110 218.09 1284.80 9750.00 3685.09 6580.54 -3678.36 9309.23 3651.95 5656.82 -456628 218.10 1281.71 9775.00 368923 6595,43 -3698.44 9353.65 3651.90 5687.85 -4598.07 218.12 1278.34 9800.00 368937 6610.33 -3718.52 9397.87 3651.58 5719.22 -462923 218.15 127460 9825.00 3685.51 6625.22 -3738.60 9419.91 3651.38 5734,98 -4644.64 21117 1270.67 9850.00 368565 6640.11 -3758.68 9439.12 3651.28 5748.65 -4658.13 218.18 1266.84 9875.00 3685.79 6655.00 -3778.76 9458.35 365125 5762.29 -4671.69 218.19 126112 9900.00 368993 6669.89 -379814 9477.61 3651.29 5775.88 -4685.34 218.20 1259.51 9925.00 3686.07 6684.79 -3818.92 9496.90 3651.41 5789.42 -4699.07 218.20 1256.00 9950.00 368621 6699.68 -3839.00 9523.24 3651.61 5807,89 -4717.84 218.21 125254 9975.00 3686_35 6714.57 -3859.08 9550.04 3651.74 5826.71 -4736.92 218.21 1249.04 10000.00 3686.50 6729.46 -3879.16 9576.82 3651.81 5845.56 -4755.95 218,22 1245.50 10025.00 3686.64 6744.36 -3899.24 9602.86 3651.81 5863.91 -477443 218.23 124192 10045.25 3686.75 6756.42 -3915.50 9622.82 3651.65 5877.98 -4788.58 21825 1239.01 10050.00 3686.77 6759.25 -3919.32 9627.49 3651.58 5881.28 -4791.89 218.20 123823 1006328 3686.80 6767.14 -3930.00 9640.58 3651.36 5890.51 -4801.17 218.06 1236.40 10075.00 3686.78 6774.08 -3939.44 9652.11 3651.09 5898.64 -4809.34 217.92 123467 10100.00 3686.60 6788.83 -3959.63 9676.70 365034 5915.98 -4826.76 217.63 1230.90 10125.00 3686.23 680148 -3979.88 9698.29 3649.47 5931.19 -4842.05 217.33 122702 10150.00 3685.68 6818.04 -4000.19 9716.34 3648.77 5943.85 -4854.90 217.01 1223.15 1017510 3684.94 6832.50 -4020.57 9734.42 3648.11 5956.46 -4867.84 216.69 1219.29 10178.68 3684.82 6834.62 -4023.58 9737.08 3648.02 5958.31 -4869.75 216.64 1218.72 10200.00 3684.09 6846.91 -4040.99 975291 3647.52 5969.01 -4880.86 216.64 121549 10225.00 368323 6861.31 -4061.41 9770.64 3646.97 5981.51 -4893.98 216.64 1211.82 10250.00 3682.37 6875.71 -4081.83 9788.68 3646.49 5993.89 -4907.10 216.64 120829 10275.00 3681.51 6890.11 -4102.24 9806.13 3645.98 6005.77 -4919.86 216.64 1204.91 10300,00 368165 6904.51 -4122.66 9823.60 3645.38 6017.60 -4932.70 21664 120167 10325.00 3679.79 6918.91 -4143.08 9841.10 3644.70 6029.37 -494564 216.65 1198.59 10350.00 3678.93 6933.31 -4163.50 9858.62 364193 604107 -4958.66 216.66 1195.65 10375.00 3678.08 6947.71 -4183.92 9876.17 3643.06 6052.71 -497176 216.67 1192.87 10400.00 3677.22 6962.11 -4204.33 9896.93 3642.03 6066.40 -4987.33 216.69 1190.21 10425.00 3676.36 6976.51 -4224,75 9918.58 3641.12 608063 -5003.62 216.70 118763 10450.00 3675.50 6990.91 -4245.17 9940.24 3640.40 6094.83 -5019.96 216.70 1185.11 10475.00 3674.64 7005.31 -4265.59 9961.92 363916 6109.00 -5036.36 216.70 1182.66 10500.00 3673.78 7019.71 -4286.01 996465 3639.48 6123.81 -505361 21668 1180.27 10521.35 3673.05 7032.01 -4303.45 1000616 3639.25 6137.80 -5069.93 216.66 117824 End of results Drilling Office 2009.1.745.0 Nikaitchuq\Oliktok Point\0111-01\OP11-101\0111-01(P4) 8/11/2010 12:39 PM Page 3 of 5 Field: NikaftcAuq Well: OP00-04 Structure: Otddok Point Borehole: OP08-04P81 Slot: OP08 Trajectory. 0P06•04PB1 Client: ENt Type: Del Survey Structure MAS: 4.159(ft) Coordinate System: NAD27 Alaska State Plane,Zone 04,US Feet North Reference: True Grid Convergence Angle: 0.12885757° Odd Scale Factor: 0.99990032 Magnetic Declination: 21.581° Magnetic Declination Date: June 26,2010 Magnetic Model: BGGM 2010 Reference Point: Northing €9$= Elevation Structure Unc.NSd) Slot Unc.tlad) 8036550.670(flUS) 516703.940(SUS) 53.300(ft)MSl 0.000(ft) 0.000(ft) Reference Cylinder North MD Reference ND Reference NS Reference Offset MD Offset ND Offset NS Offset EW Azim Ct-Ct Distance (ft) (ft) (ft) (ft) (ft) (ft) (6) (9) (°) (0) Absolute minimum indicated. Results filtered:Depth 3600.00 ft<=TVD<=3700.00 It Results filtered:Ct-Ct separation<=1320.00 ft Results highlighted:Ct-Ct separation<=1320.00 ft 5900.00 3603.12 372803 -1267.92 6017.21 3654.65 3820.41 -116.49 78.30 115628 5925.00 3607.67 375160 -1274.89 6039.20 365644 3842.25 -118.29 78.12 1161.17 5950.00 3611.90 3775.24 -1281.83 605826 365803 3861.18 -119.82 77.99 1166.10 5975.00 3615.81 3798.95 -1288.73 607472 3659.40 3877.54 -121.02 77.87 1171.16 6000.00 361941 3822.72 -1295.59 6091.15 3660.76 3893.88 -122.12 77.76 1176.35 6025.00 3622.68 3846.55 -1302.41 6107.56 3662.10 3910.20 -123.10 7765 1181.68 6050.00 3625.64 3870.43 -1309.19 6123.92 3663.41 3926.49 -123.97 77.56 1187.15 6075.00 362627 3894.36 -1315.93 6140.25 366472 3942.76 -124.72 77.47 1192.74 6100.00 3630.58 3918.34 -132262 6158.98 3666.19 3961.41 -125.48 77.39 1198.45 6124.46 3632.53 3941.84 -1329.13 6178.30 3667.68 3980.65 -126.18 77.31 1204.09 6125.00 3632.57 3942.35 -1329.27 6178.72 3667.72 3981.08 -126.19 77.31 1204.22 6148.46 3634.30 3964.91 -1335.49 6197.21 3669.12 3999.51 -126.79 77.31 1209.70 6150.00 3634.41 3966.39 -1335.90 6198.42 366921 4000.71 -126.83 77.34 1210.06 6173.62 3636.19 3989.13 -1342.03 6217.03 367060 401926 -127.36 77.89 121563 6175.00 3636.30 3990.46 -1342.39 6218.12 3670.68 4020.34 -127.39 77.89 121685 6200.00 3638.23 4014.55 -1348.76 6237.80 3672.12 4039.96 -127.88 77.86 1221.62 622500 3640.18 4038.65 -1355.14 6260.91 3673.79 4063.01 -128.39 77.86 1227.46 6250.00 3642.10 4062.74 -1361.52 6284.51 3675.46 4086.55 -128.89 77.84 1233.31 627500 3644.03 4086.64 -1367.90 6308.11 3677.11 4110.08 -129.39 77.83 1239.17 6300.00 3645.96 4110.94 -137428 6331.69 3678.73 4133.61 -129.86 77.81 1245.05 6316.78 3647.26 4127.10 -1378.56 6347.20 3679.79 414907 -130.17 77.79 1249.00 6325.00 3647.89 4135.03 -138067 6354.73 3680.32 4156.58 -130.31 77.59 1250.96 635000 3649.77 4159.07 -1387.26 6377.56 3681.95 4179.36 -130.74 76.99 1257.10 6375.00 3651.59 4183.04 -1394.11 6400.33 3683.65 4202.05 -131.13 76.38 1263.52 6400.00 3653.34 4206.95 -1401.21 6423.01 3685.40 4224.67 -131.51 75.78 1270.23 6425.00 3655.03 4230.78 -1408.57 6442.53 3686.94 4244.12 -131.79 75.18 1277.25 645000 3656.66 4254.54 -1416.18 6459.93 3688.31 4261.46 -131.96 74.58 1284.63 647500 3658.23 427822 -1424.05 6477.21 368964 4278.69 -132.05 73.97 1292.39 6500.00 3659.73 4301.81 -1432.17 6494.37 3690.94 4295.81 -132.04 73.36 1300.52 6525.00 3661.17 4325.33 -1440.54 6511.41 3692.21 4312.80 -131.95 72.75 1309.02 6550.00 3662.54 4348.75 -1449.16 6528.32 3693.46 4329.66 -131.78 72.13 1317.89 End of results Drilling Office 2009.1.745.0 Nikaitchuq\Oliktok Point\0111-01\OP11-101\0111-01(P4) 8/11/2010 12:39 PM Page 4 of 5 Field: N&atchuq Well: OP08-04 Structure: Orbdok Point Borehole: OP08-04 Slot: OP08 Trajectory: OP08-04 Client: ENI Type: Dal Survey Structure MAS: 4.159(It) Coordinate System: NAD27 Alaska Slate Plane,Zone 04,US Feet North Reference: True Grid Convergence Angle: 0.12885757° Odd Scale Factor: 0.99990032 Magnetic Declination: 21.564° Magnetic Declination Date: July 08,2010 Magnetic Model: BGGM 2010 Reference Point: Northing Fasting faMila Structure Unc.I1sd) Slot Unc.11ad) 8036550.670(ftUS) 516701940(BUS) 53.300(ft)MSL 0.000(ft) 0.000(ft) Reference Cylinder North MD Reference TVD Reference NS Reference EW Offset MD Offset TVD Offset NS Offset EW Azim Ct-Ct Distance (ft) (ft) (ft) (ft) (ft) (ft) (ft) (ft) (� (ft) ' Absolute minimum indicated. Results filtered:Depth 3600.00 ft<=TVD<=3700.00 ft Results filtered:Ct-Ct separation<=1320.00 ft Results highlighted:Ct-Ct separation<=1320.00 It 5900.00 3603.12 3728.03 -1267.92 6017.21 3654.65 3820.41 -11649 78,30 1156.28 5925.00 3607.67 3751.60 -1274.89 6039.20 3656.44 3842.25 -11829 78.12 1161.17 5950.00 3611.90 3775.24 -1281.83 6058.26 365863 3861.18 -119.82 77.99 1166.10 5975.00 3615.81 3798.95 -1288.73 6074.72 3659.40 3877.54 -121.02 77.87 1171.16 6000.00 3619.41 3822.72 -1295.59 6091.15 3660.76 3893.88 -122.12 77.76 1176.35 6025.00 3622.68 3846.55 -1302.41 6107.56 3662.10 3910.20 -123.10 77.65 1181.68 6050.00 3625.64 3870.43 -1309.19 6123.92 366341 3926.49 -123.97 77.56 1187.15 607560 3628.27 3894.36 -1315.93 6140.25 3664.72 3942.76 -124.72 77.47 1192.74 610000 3630.58 3918.34 -1322.62 6158.98 3666.19 396141 -125.48 77.39 119845 6124.48 363253 3941.84 -1329.13 6178.30 3667.68 3980.65 -126.18 77.31 1204.09 6125.00 363267 3942.35 -1329.27 6178.72 3667.72 3981.08 -126.19 77.31 1204.22 6148,46 363430 3964.91 -1335.49 6197.21 3669.12 3999.51 -126.79 77.31 1209.70 6150.00 3634.41 3966.39 -1335.90 6198.42 366921 4000.71 -126.83 77.34 1210.06 6173.62 3636.19 3989.13 -1342.03 6217.03 3670.60 401926 -127.36 77.89 1215.53 6175.00 3636.30 3990.46 -1342.39 6218.12 3670.68 4020.34 -127.39 77.89 1215.85 6200.00 363823 4014.55 -1348.76 6237.80 3672.12 4039.96 -127.88 77.88 1221.62 6225.00 3640.16 4038.65 -1355.14 6260.91 3673.79 4063.01 -128.39 77.86 1227.46 6250.00 3642.10 4062.74 -1361.52 6284.51 3675.46 4086.55 -128.89 77.84 1233.31 6275.00 364403 4086.84 -1367.90 6308.11 3677.11 4110.08 -129.39 77.83 1239.17 6300.00 364566 4110.94 -1374.28 6331.69 3678.73 4133.61 -129.86 77.81 1245.05 6316.78 3647.26 4127.10 -1378.56 6347.20 3679.79 4149.07 -130.17 77.79 124960 6325.00 3647.89 4135.03 -1380.67 6354.73 3680.32 4156.58 -130.31 77.59 125(196 6350.00 364917 4159.07 -1387.26 6377.56 3681.95 4179.36 -130.74 76.99 1257.10 6375.00 3651.59 4183.04 -1394.11 6400.33 3683.65 4202.05 -131.13 76.38 1263.52 6400.00 3653.34 4206.95 -1401.21 6423.01 368540 422467 -131.51 75.78 1270,23 642560 3655.03 4230.78 -1408.57 6442.53 3686.94 4244.12 -131.79 75.18 1277.25 6450.00 3656,66 4254.54 -1416.18 6459.93 3688.31 4261.46 -131.96 74.58 1284.63 6475.00 3658.23 4278.22 -1424.05 6477.21 3689.64 4278.69 -132.05 73.97 1292.39 650600 3659.73 4301.81 -1432.17 649437 3690.94 4295.81 -132.04 73.36 1300,52 6525.00 3661.17 4325.33 -1440.54 6511.41 369221 4312.80 -131.95 72.75 1309.02 6550.00 3662.54 4348.75 -1449.16 6528.32 3693.46 4329.66 -131.78 72.13 1317.89 9525.00 3684.17 6445.92 -3498.08 11098.92 3726.95 7575.17 -2820.36 3920 1317.70 9550.00 3684.16 6461.08 -3517.96 11123.77 3723.38 7587.92 -2841.39 39.04 1314,94 9559.61 3684.15 6466.91 -3525.61 11130.94 3722.28 7591.60 -2847.44 39.00 1313.88 956341 3684.15 6469.21 -3528.63 11133.77 3721.85 7593.06 -2849.83 38.90 1313.47 9575.00 3664.16 647621 -3537.87 11142 40 3720.47 7597.50 -2857.10 38.62 1312.27 9600.00 3684.25 6491.19 -3557.88 11161.28 3717.32 7607.27 -2872.94 38.01 1309.92 9601.35 3684.26 6491.99 -3558.97 11162.34 3717.15 7607.82 -2873.83 37.98 1309.80 9625.00 3684.39 6506.08 -3577.96 11181.75 3714.03 7617.95 -2890.10 37.84 1307,77 9650.00 3684.53 6520.97 -3598.04 11206.34 3710.16 7630.79 -2910.70 37.66 1305.68 9675.00 3684.67 6535.86 -3618.12 11230.93 3706.29 7643.64 -2931.30 37.49 1303.59 9700.00 3684.81 6550.76 -3638.20 11240.00 370487 7648,38 -2938.91 37.42 1301.61 9725.00 3684.95 6565.65 -365828 11240.00 3704.87 7648.38 -2938.91 37.42 1300.08 9750,00 3685.09 6580.54 -3678.36 11240.00 370487 7648.38 -2938.91 37.42 1299.03 9775.00 3685.23 6595.43 -3698.44 11240.00 370487 7648.38 -293691 37.42 1298.45 9800.00 3685.37 6610.33 -3718.52 11240.00 3704.87 7648.38 -2938.91 37.42 1298.36 9825.00 3685.51 6625.22 -3738.60 11240.00 3704.87 7648.38 -2938.91 37.42 129875 9850.00 3685.65 6640.11 -375868 11240.00 3704.87 7648.38 -2938.91 3742 1299.62 9875.00 3685,79 6655.00 -3778.76 11240.00 3704.87 7648.38 -2938.91 37.42 1300.97 9900.00 3685.93 6669.89 -3798.84 11240.00 3704.87 7648.38 -2938.91 37,42 1302.80 992560 3686.07 6684.79 -3818.92 11240.00 3704.87 7648.38 -2938.91 37.42 1305,10 9950.00 3686.21 6699.68 -3839.00 11240.00 370467 7648.38 -293691 37.42 1307.88 9975.00 3686.35 6714.57 -3859.08 11240.00 3704.87 7648.38 -2938.91 37.42 1311.13 10000.00 3686.50 6729.46 -3879.16 11240.00 3704.87 7648.38 -2938.91 37.42 1314,85 10025.00 3686.64 6744.36 -3899.24 11240.00 3704.87 7648.38 -2938.91 37.42 1319.03 End of results Drilling Office 2009.1.745.0 Nikaitchuq\Oliktok Point\0111-01\OP11-101\0111-01(P4) 8/11/2010 12:39 PM Page 5 of 5 TRANSMITTAL LETTER CHECKLIST WELL NAME /`1f .�C� :� /( '/ PTD# /C' /67)c. Development Service Exploratory Stratigraphic Test Non-Conventional Well /' FIELD: � //CL L POOL: A / � 7,�A-47-e,!4(e 1 / Circle Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in Permit No. ,API No. 50- - - API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full complia ith 20 AAC EXCEPTION 25.055. Approval to perforate and eroduce / in'ect is ontingent upon issuance of a onservation orde�'j au: • ' . a spacing exception. �—�� /,.(J( eyjhi (to.. 1C. assumes the liability of any protest to th�pacing Oception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non-Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev: 1/11/2008 aQ Co H O N N a(n N° _° ° °p m E a) c c o as Q a) L > a a)a c °w O M V c C O °- ° I11 (a Z ° a) N - 'OD a) d o n E E wO L Ct W co a, c° n n c w O = w j co co N E O O z 0 0 O� (o o C ° m C 0 CA co a)F 2 �O "c O O L O) Y N d () d (-si V § C O M N Q U O 0 C O O 0 x 0 a)U O U) O a) ai co °_ O a) ' , J ° c CO N > a ° 0 a o (n N a) 3 0 O .- O Q ° o a m U D m co a aa)) m co o w E 3 .. t CN Q ai .E co ° N 0) m E ai .c z rn 3 0 ° v • 0 ai a a To v a) w ° p to J '� N CO @ 0 M_ a) a) ° a LLI L w o (n Q L C N O a O O a0 l00 co L N a U) _ co Q F- o o- a N m •E CO n 3 w cl 3 a o o c p 0 ° o c 1a 0 ' '(0 Q 0 U) o o a),- O a p in C n N o. o z °) n a a°ci N° 7 Q N O 40 1- w o 0 o co N 0 3 rn O (n co N o O O n a) o LO m U 3 m z c cco LL. ca 4- L I I a) L ° E n 0 a cc; N z c a U 0 0 o0 co 2 - Cr) 3 c w o a) ° ° a) O z co O ° ° 0 0 - o p > Y co coi p 3 1- c o c c m aa) °- z co Z m o. w ac) 0 Z N- CA O in d O .. • f) C .N..� N : 2 a ai N 'O W o-° ° J M d c U c C C p C a) O fa a >. a o" n ° a) a) . 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N a N O N C L a co 3 co o a) . .E m ` m 0 0 0@ (n o c .� a = C .N a .N o n _ _ n a) 3 C _ c TD d �° o CO c c N T ° ° a m E 6 a`) c co ° n o c0i o ° ° O T a) LL 0 a7 - N N N N C N N L a) • N @ -0 ") O .� 0 L 3 a s 0 va)) C 00 O N LC 0 C CC N co ° E a) 0 0 L m a) 3 0 ° o U as m o ° = a) a zt co - 0 0 m N co U c I- 7 a3i v v v @ `o o «0 0 aE`> v U) ap c a) - o - a •0 -`o 0 r h o- E m 'E 0 2 c.) a Jw .E N Q o 0 0 g '� a`) a) E E c' 0 3 °- o a of I- I- I- .S 2 ao.) a) a a a o Y 5 E m m m c m ° .0 ° ° (1) 0 a n n o Cl) co ° - 2 o o 0 2 2 2 ca a ca a V = 0 0 L 0 0- a) o a) a) a) 0 0 V@ a J D cn O O a a U Q a z U co U U U U Q ' Q ' a m CO U 2 a Q cn cn U W Q O - N CO V U) CO h CO 0) 0 N CO V U) (O I- CO C)) 0 N CO V U) CO N- CO 0) I E N co V CO CO N- 00 o) N N N N N (N N N Cs) N C`') co co co co co co co Co) co U O O O O O c N U O O C O c 16 CO Ce 6 W M Q O O fa)/) W o co ao c w °o o f d N N a) ✓a C0 o 2 c O c O 0 W O E a c a -I a 5. a U a ° a 0 a. .2 w I, Well History File APPENDIX Infou n ration of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically • organize this category of information. Tot 2no Einiii Petirolleum FINAL WELL REPORT MUDLOGGING DATA NIKAITCHUQ 0111-01 and PB1 OLIKTOK POINT, ALASKA y 5� iii E?i' f • • A y - cJ J,` -� }� " .� CANRIG DRILLING TECHNOLOGY LTD. Approved by: Andrew Buchanan Compiled by: John Lundy Emil Opitz Zachary Beekman Jeff McBeth Distribution: November 28, 2010 Date: September 6, 2010 a-l0 -1OG fit 0111-01 and PB1 TABLE OF CONTENTS 1 MUDLOGGING EQUIPMENT& CREW 3 1.1 Equipment Summary 3 1.2 Crew 4 2 WELL DETAILS 5 2.1 Well Summary 5 2.2 Hole Data 5 2.3 Well Synopsis 6 3 GEOLOGICAL DATA 7 3.1 Target and Offset Well Data 7 3.2 Formation Tops. 8 3.2.1 Surface and Intermediate Section 8 3.2.2 Production Section 9 3.3 Lithologic Descriptions/Stratigraphy 10 3.4 Connection Gas Summary 27 3.5 Trip/Wiper Gas Summary 27 3.6 Sampling Program And Sample Dispatch 28 4 PRESSURE AND FORMATION STRENGTH DATA 29 4.1 Pore Pressure Gradient Evaluation 29 4.2 Quantitative Methods 29 5 DRILLING DATA 30 5.1 Daily Activity Summary 30 5.2 Survey Data 33 5.3 Bit Record 36 5.4 Mud Record: Surface and Intermediate Hole 37 5.5 Mud Record: Production Hole 38 6 DAILY REPORTS 39 Enclosures 2"/100' Formation Log (MD and TVD) 2"/100' Gas Ratio Log (MD and TVD) 2"/100' LWD Combo Log (MD and TVD) 2"/100' Drilling Dynamics Log (MD and TVD) Show Reports Final Data CD 2 C,AM1G Jeni 0111-01 and PB1 1 MUDLOGGING EQUIPMENT & CREW 1.1 Equipment Summary Parameter Equipment Type/Position Downtime Comments (hours) Casing Pressure Cable to 1502 transducer for BOP 0 tests only. Computer—Drill Floor Monitor Azonics 0 Computer—Pit Monitor Azonics 0 Computer for Company Man, RigWatch Remote(HP Compaq) 0 camp Computer for Company Man/ RigWatch Remote(HP Compaq) 0 Toolpusher, office (wireless) Computer for Mud Engineer RigWatch Remote(HP Compaq) 0 Computer for Toolpusher RigWatch Remote(HP Compaq) 0 Computers for Mudloggers (3) Data editing, RigWatch Master, and 0 RigWatch Remote(all HP Compaq) QGM Agitator (Mounted in possum belly) g as Ditch Flame Ionization Detector(FID) 0 Total Gas and Chromatography. Hook Load/Weight on bit Drilling Line Sensor on Rig Floor 0 Mud Flow In Derived from Strokes/Minute and 0 Pump Output Mud Flow Out Flow line Sensor 0 Pit Volumes, Pit Gain/Loss 10 radar pit sensors 0 Pump Pressure Standpipe Transducer 0 Pump stroke counters(3) 2 proximity sensors 0 Rate of penetration Draw Works Encoder 0 RPM PLC feed 0 Torque PLC feed 0 Wits In (LWD Data) LWD Computer to RigWatch 0 Master Computer Ila eni. 0111-01 and PB1 1.2 Crew Unit Number: ML059 Unit Type: Arctic/Steel Mudloggers Years of Days at Sample Days at Technician Days at Experience 011101 Catchers 0111-01 0111-01 John Lundy 18 9 Steve Pike 9 Allan Williams 4 Tollef Winslow 2 12 Larry Resch 21 Howard Lamp 2 Emil Opitz 2 7 Dan Sherwood 17 Zach Beekman 2 14 Steve Franzen 5 Jeff McBeth 2 10 (note: spudded 9/22) �� 4 CAN RIG ilk eni 0111-01 and PB1 2 WELL DETAILS 2.1 Well Summary Well: Nikaitchuq 0111-01 API Index#: 50-029-23430-00-00 Field: Nikaitchuq Surface Co-Ordinates: 2,186.2 FSL 1,597.2 FEL Sec 5 T13N R9E UM Borough: North Slope Primary Targets: OA Sand of the Schrader Bluff State: Alaska Primary Target Depth: 5941.0'; -3561.0' Rig Name/Type: NAD 245E/Arctic/Triple TD Depth: 10594.77'; -3634.4'TVDSS Spud Date: September 22, 2010 Ground Elevation: 12.2' MSL TD Date: October 8, 2010 RT Elevation: 53.25' MSL Days Drilling: 17 TD Formation: Schrader Bluff OA Sand Classification: Injector 2.2 Hole Data Maximum Depth Mud Shoe Depth LOT Hole TD Weight Dev. Casing/ (ppg) Section MD TVD Formation ( inc) Liner MD TVD (ft) (ft) (PR) (ft) (ft) Conductor 160 160 Recent 8.8 0 - - - - 16"Surface 2347 2160.5 Ugnu 9.3 42 13-3/8" 2334.7 2160.5 12.1 Schrader 12-1/4" 6007 3653.6 Bluff, OA 9.15 81 9 5/8" 5990.9 3598.3 12.84 Sand Schrader 8-1/2" 10594 3687.9 Bluff, OA 8.7 90.15 4 1/2" 10594 3687 - Sand w� 5 CAR emi 0111-01 and PB1 2.3 Well Synopsis The Borehole extends from the surface to a TD at 6976' MD MD/3665.7' TVD/-3612.45" TVDSS where directional control became problematic and an open hole sidetrack was performed. The borehole has three sections designated by hole diameter: 16"Surface; 12-1/4"Intermediate;8-1/2"Production Lateral. This well was designed as an injection well. 01 11-01-PB1 was spudded on September 22,2010,entering a pre-set conductor pipe at a depth of 160'. 16" hole was drilled to a depth of 2347'. 13-3/8", 681b surface casing was set at 2334.7'MD/2160.5"TVD/- 2107.42'TVDSS. The float equipment and shoe were drilled out and new hole was drilled to 2367".A Leak Off Test was performed to 12.1 ppg. The intermediate section was drilled with a hole diameter of 12-1/4" to a depth of 6007'MD. The hole was back-reamed to the existing casing shoe and circulated clean.After laying down the drilling assembly, 9 5/8"; 471b/foot casing was set at 5990.9' MD/ 3651.5' TVD. An 8.5" bit and drilling assembly were picked up and run in to the surface casing shoe.Sonic log was performed from surface casing shoe to TD for cement evaluation. The 9 5/8"casing shoe was drilled out with additional new hole to 6027'where a leak off test was performed yielding 12.84 PPG/MWE.Normal drilling was resumed using an 8 1/2" PDC bit and the borehole extended to 6977' MD where target acquisition became problematic and an open hole sidetrack was performed at 6327'MD. Drilling resumed at 6327'MD using the 8 1/2" PDC bit and well 0111-01 was drilled to TD of 10,594'MD. A USIT/CBL Log was performed after running the 51/2 liner for cement evaluation. 6 CANRI7 IX eni 0111-01 and PB1 3 GEOLOGICAL DATA 3.1 Target and Offset Well Data 0111-01 Offset Well Data Original Zone or Horizon Prognosed P03- OP-11 OP-12 OP26- Depth (ft) PO5PB1 PB01 DSPO2 MD TVDSS TVDSS TVDSS TVDSS TVDSS SV-4 709.7 -656.2 -657.7 -659.1 SV-3 967.1 -910.8 -907.6 -902.8 SV-2 1238.2 -1168.7 -1174.0 -1169.0 -1163.2 SV-1 1767.1 -1638.3 -1671.1 -1671.2 -1647.0 -1648.1 Permafrost Base 1890.2 -1725.0 -1722.1 -1726.8 -1724.3 Ugnu Top(UG4) 2156.4 -1968.1 -1984.8 -1984.8 -1931.5 -1957.2 13 3/8" SCP 2356.6 -2120.0 UG-2 Coal Marker 2906.0 -2441.5 -2512.7 -2488.2 -2422.0 -2428.2 Fault 1 4188.8 -2940.4 L Ugnu 4673.5 -3127.7 -3140.3 -3274.3 -3060.0 -3122.5 Schrader Bluff 5168.0 -3318.8 -3387.3 -3511.3 -3341.9 -3325.0 N Sand Top 5363.7 -3393.6 -3470.7 -3596.2 -3382.6 3382.6 N Sand Bottom 5627.2 -3481.0 -3523.5 -3640.5 -3424.4 -3423.3 OA Sand Top 5962.9 -3561.3 -3789.6 -3518.2 -3536.4 0A2 6043.0 -3572.4 5934.0 9 7/8" ICP 6128.4 -3580.6 5990.9 Total Depth 10521.9 -3620.0 6976.0 CA�� qq��''rr 7 N RIG eni 0111-01 and PB1 3.2 Formation Tops: 3.2.1 Surface and Intermediate Section Depth (ft) Current Proanosed Depth (ft) Zone or Horizon MD TVD TVDSS MD TVD TVDSS 20"Conductor Shoe 160.0 160.0 -106.7 160.0 160.0 -106.8 SV-4 712.7 712.3 -659.1 709.7 160.0 -656.2 SV-3 968.0 964.2 -911.0 967.1 709.5 -910.8 SV-2 1243.5 1226.1 -1172.9 1238.2 964.1 -1168.7 SV-1 1768.4 1694.0 -1640.7 1767.1 1222.0 -1638.3 Permafrost Base 1854.0 1770.2 -1717.0 1890.2 1691.6 -1725.0 Ugnu Top(UG4) 2156.0 2024.1 -1970.9 2156.4 1778.3 -1968.1 13 3/8"Casing Shoe 2334.7 2160.5 -2107.2 2356.6 2021.3 -2120.0 TD 16"Surface Hole 2347.0 2169.6 -2116.4 2356.6 2173.3 -2120.0 UG-2 Coal Marker 2818.1 2483.0 -2429.7 2906.0 2495.0 -2441.7 Fault 1 Not seen 4188.8 2998.6 -2945.3 Lower Ugnu 4612.0 3182.0 -3128.8 4673.5 3181.0 -3127.7 Schrader Bluff 5178.2 3385.9 -3332.7 5168.0 3372.0 -3318.8 N Sand Top 5403.0 3466.3 -3413.1 5363.7 3447.1 -3393.8 N Sand Base 5516.0 3509.4 -3456.2 5627.2 3490.0 -3436.7 OA sbll 5874.0 3626.1 -3572.9 5941.0 3614.3 -3561.0 OA sbl2 5934.0 3640.0 -3586.6 6294.0 3632.9 -3579.6 OA sbl2 5970.0 3647.5 -3594.3 9 5/8"Casing Shoe 5990.9 3651.5 -3598.3 6315.0 3634.6 -3581.3 TD 12 1/4" Borehole 6007.0 3654.4 -3601.2 6315.0 3634.6 -3581.3 8 CANRIG eni 0111-01 and PB1 3.2.2 Production Section Zone or Horizon Depth (ft) Prognosed Depth (ft) MD TVD TVDSS MD TVD TVDSS OA sb13 6318.0 3667.3 -3614.1 Fault 1 6370.0 3666.9 -3613.7 OA sb12 6678.0 3671.8 -3618.6 OA sbl2 6962.0 3677.9 -3624.6 OA sbl3 7365.0 3688.9 -3635.6 Fault 2 7636.0 3701.5 -3648.2 7900.0 OA sbll 7760.0 3709.7 -3656.5 OA sbl2 7990.0 3716.4 -3663.2 OA sbl3 8204.0 3724.7 -3671.5 Fault 2 9061.0 3728.3 -3675.1 8600.0 Base OA 9190.0 3717.2 -3664.0 OA sbl4 9257.0 3710.6 -3657.4 OA sbl3 9447.0 3696.5 -3643.3 OA sbl2 9695.0 3693.4 -3640.2 TD 8 1/2" Borehole 10594.0 3687.6 -3634.4 10506.0 3673.3 -3620.0 9 CANIRIG am_ 0111-01 and PB1 3.3 Litholoqic Descriptions/Stratigraphv The Permafrost section of the 0111-01 consists of moderate beds of sand,conglomerate and claystone with thinner clay interbeds,particularly near the surface.This material is almost entirely included in the permafrost section and contained no oil shows; some minor methane hydrates were encountered. PERMAFROST AND RECENT/QUATERNARY DEPOSITS SURFACE TO 2156.0'MD/-1970.9'TVDSS This interval extends from surface down to the top of the Ugnu at 2156.0' MD and is comprised of a thick sequence of sands, conglomerates and claystones with occasional thin to massive siltstone and poorly developed coals and carbonaceous remains. Sand dominates the upper part of the section with claystone becoming predominant with depth Discrete fragments of sandstone were rarely observed, samples were typified by loose sand and conglomeritic pebble fragments with irregular globular clay masses. Clay masses commonly contained trace to abundant sand mechanically worked into the clay by drilling, circulation and shaker action and had a surface coating of imbedded loose sand. Formation consists of moderate to thick beds with locally abundant thinner interbeds. No unforeseen problems were encountered drilling this section, and no marketable hydrocarbons were found. Drill Rate(ft/hr) Total Gas(units Maximum Minimum Average Maximum Minimum Average 450.2 13.9 106.7 138 0 19.7 PEAKS Depth TG C1 C2 C3 C4I C4N C5I C5N 1363 16 5252 1450 37 7490 1545 63 12793 1588 77 15468 1719 57 12071 1800 113 23298 1882 94 19555 2096 123 24196 2170 138 24033 2125 119 21243 _ 2188 80 16512 Sand/Conglomeritic Sand (1000-1050') = dark grayish black to dark gray with salt pepper appearance; medium grained;subdiscoidal to spherical;angular to sub-rounded;moderately sorted;unconsolidated sand; grain supported; texturally immature; compositionally immature; quartz sand with mudstone and siltstone conglomerates;disseminated pyrite,pyrite incrusted sand grains and mudstone conglomerates;green lithics; porosity and permeability visually good; no oil indicators. Clay(1050-1110')=medium gray to medium light gray;soft;cohesive,plasticity;lumpy to clumpy consistency; elastic to stiff tenacity; earthy fracture; massive cuttings habit; dull to earthy luster; clayey texture; massive structure; sand, disseminated pyrite present; no oil. Claystone (1110-1170') = medium light gray to light gray to medium gray; very cohesive; moderately to slightly adhesive; pasty to clumpy consistency; cuttings are mechanically reworked globular masses; dull earthy luster;texture varies with amount of sand grain content within cuttings between smooth and clayey to gritty and clayey; no visible structures; free sand grains present within cuttings throughout sample interval; disseminated pyrite crystals; no oil present. eni. 0111-01 and PB1 SV-2 1243.5' MD/-1172.9' 'TVDSS Claystone(1170-1260')=medium gray to light gray through out sample interval;very cohesive;moderately to slightly adhesive;predominantly pasty to clumpy and lumpy;cuttings obtained from shakers are mechanically reworked masses; dull and earthy luster; texture is smooth clayey to clayey gritty, depending on amount of sand grains within clay masses; disseminated pyrite throughout sample interval; no oil present. Claystone(1260-1320')=medium light gray to medium gray;very cohesive;slightly to moderately adhesive; pasty to clumpy to lumpy; dull earthy luster; cuttings are masses that have been reworked into globs by drilling;smooth clayey to gritty texture, depending on amount of sand grains within claystone masses; pyrite crystals throughout sample interval both as disseminated grains and as crystal growths on and within sand and pebble grains; no oil present. Conglomerate/Conglomeratic Sand(1320-1440')=grayish black to medium gray to white to translucent to brownish gray;very coarse to small pebble sizes for conglomerate;conglomeratic sands vary from coarse to very coarse; samples also contain fine to medium free sand grains; the larger the grains are, the more rounded they tend to be; angular to rounded throughout sample interval; poor sorting; low to moderate sphericity; pyrite crystals grow on the surfaces and within sand and conglomerate grains; no oil present. Claystone(1350-1440')=medium gray to medium light gray;very cohesive;slight to moderate adhesiveness; pasty to clumpy; earthy dull luster; cuttings are mechanically reworked and come off shakers as clumpy masses;smooth clayey to gritty texture depending on amount of sand grain content;pyrite throughout sample interval both as disseminated grains and as crystal growths on and within conglomerate and sand grains; no oil present. Sand/Conglomeratic Sand(1310-1450')=translucent to grayish black to milky white with green and brown hues; upper very fine to coarse free sand grains with very coarse and occasional pebble sized grains; poor sorting; angular to sub-rounded; low to moderate sphericity; disseminated pyrite free grains and crystal growths on surfaces of sand and pebble grains; no oil present. Claystone(1440-1530') = medium light gray to medium gray throughout sample interval; moderate to very cohesive;slightly to moderately adhesive;pasty to clumpy and lumpy;dull earthy luster;cuttings come across shakers as masses that have been mechanically reworked; smooth clayey to gritty texture, becoming more gritty as depth increases and sand content increases;pyrite throughout sample interval as crystal growths on and within sand grains, and also as disseminated free grains; no oil present. Sand/Conglomeratic Sand(1450-1650')=grayish black to brownish black to translucent to milky white with some brownish and greenish hues; upper very fine to coarse free sand grains; very coarse to pebble sized conglomeratic sand grains; poor sorting; angular to sub-rounded; low to moderate sphericity; pyrite occurs throughout sample interval both as free disseminated crystalline grains and as crystal growths on the surfaces of sand and conglomerate grains; no oil present. Claystone(1590-1740')=medium gray to medium light gray to medium dark gray throughout sample interval; very cohesive; moderately to slightly adhesive when prodded; cuttings come over shakers as mechanically reworked masses; pasty and mushy to slightly clumpy consistency;dull earthy luster; smooth clayey to gritty texture depending on sand grain content; pyrite throughout sample interval both as disseminated grains and as crystalline growths on the surfaces of sand grains; no oil present. SV-1 1768.4' MD/-1640.7' TVDSS Sand(1710-1830')=grayish black to translucent to medium gray to milky white throughout sample interval with occasional brownish and greenish hues; upper very fine to coarse with some scattered pebbles shallower in hole; poorly sorted to fair sorting,with sorting becoming better as depth increases; angular to subangular; low sphericity; unconsolidated sand grains throughout sample interval; pyrite crystalline grains disseminated throughout interval, also pyrite crystal growths on the surfaces and within sand grains; no oil present. 11 CANRIG eni. 0111-01 and PB1 PERMAFROST BASE 1854.0' MD/-1717.0'TVDSS Clay (1830-1950') = medium gray to medium dark gray; soft; poorly indurated elastic to flexible tenacity; earthy fracture; massive cuttings habit; earthy to dull luster; clay texture; massive structure; cohesive, plasticity; lumpy to clumpy consistency;sand mixed with clay can be interpreted as interbedding;translucent quartz sand, upper fine to lower fine grained, spherical to subdiscoidal, angular to subangular; moderately sorted, unconsolidated sand, grain supported; carbonaceous shale/silt (1% - 3%') brownish black, hard to moderately hard, moderate to well induration,grades between silt and shale, laminae structure;disseminated pyrite, also grain incrusted pyrite; green lithics; no oil indicated. Sand(1920-2010')=grayish black to dark gray; upper fine to lower medium grains;spherical to subdiscoidal; angular to sub-rounded; moderate to moderately well sorted; unconsolidated sand; grain supported; translucent quartz grains; siltstone mixed with quartz grains of upper fine to lower medium grain size fragments, hard, well indurated, brittle tenacity, irregular fracture, wedge like cuttings habit, silty texture, massive structure, some siltstone has reddish carbonaceous material; black carbonaceous lithics present; green and moderate red lithics present; non-calcareous; no oil indicators. Clay(2010-2080') = medium dark gray to medium gray with olive gray sub tones; cohesive, adhesive and plasticity;slimy to tacky consistency;elastic to flexible tenacity;earthy fracture;massive cuttings habit;waxy to earthy luster;clayey to silty texture;massive observed structure, laminae to thin beds of sand can be inferred; sand, upper medium to lower fine,spherical to subdiscoidal,angular to subangular,moderate sorting;siltstone fragments mixed with sand grains; carbonaceous siltstone fragments; no oil indicators. Carbonaceous Shale/Coal(2080-2100')=grayish black to black with reddish brown streaks;firm friable to moderately hard; brittle tenacity;planar fracture;blocky cuttings habit;resinous to greasy luster;matte texture; laminae structure;faint out gassing observed;carbonaceous shale grades to low grade lignitic coal and back. Sand (2100-2160') = olive gray to light olive gray; medium lower to fine upper grains; subdiscoidal to spherical;subangular to angular;moderate sorting; unconsolidated sand;grain supported;texturally immature; compositionally immature; translucent and brownish red quartz; medium grained siltstone present, carbonaceous material; no oil indicators. UGNU 2156.0'MD/-1970.9'TVDSS TO 5178.2' MD/-3332.7'TVDSS The Ugnu is an Upper Cretaceous and Lower Tertiary shallow marine and deltaic deposit. The Ugnu, in places, contains oil which is bitumen and extra heavy crude with API gravities between 8° and 12°. Upper Ugnu (also known as the "L" sand) was encountered at 1970.9' MD, continuing to the Lower Ugnu / ( "M" sand)at 4612'MD and leaving the Ugnu at it's contact with Schrader Bluff at 5178" MD, Fault#1 having not been identified on logs. The Upper Ugnu is characterized by interbedded layers of sand, sandstone and claystone with occasional coal beds. The sands are primarily upper fine to lower medium in size. At 2818'MD the UG-2 Coal Bed Marker was encountered. The Lower Ugnu is an unconsolidated sand of upper fine to lower medium grains with thin beds of carbonaceous material. No recoverable hydrocarbons were encountered and only minimal oil indicators were seen. Drill Rate(ft/hr) Total Gas(units Maximum Minimum Average Maximum Minimum Average 717.8 0.6 157.8 79 0 15.7 PEAKS Depth TG C1 C2 C3 C4I C4N C51 C5N 2188 79 16512 2533 45 8465 2707 38 7657 12 CANRIG Olt eni 011 1-01 and PB1 2812 60 12614 3295 26 5184 3407 48 9352 3732 41 8336 3799 52 10684 4045 32 6499 4108 40 8010 Clay (2160-2250') = medium gray to medium dark gray; cohesive and plasticity; tacky to stiff consistency; earthy fracture; massive cuttings habit; dull to waxy luster; gritty to silty to clayey texture; massive structure; sand entrained with in clay;translucent quartz,lower medium to upper fine,spherical to subdiscoidal,angular to subangular, moderate sorting, sand unconsolidated; carbonaceous shale, pyrite and green lithics; no oil. Sand (2250-2347') = dark gray to medium dark gray; upper medium to lower fine grains; spherical to subdiscoidal;angular to subangular;moderately well sorted; unconsolidated sand;grain supported;texturally immature; compositionally immature; translucent and white quartz grains with impacting; carbonaceous material,green lithics,occasional pinkish orange lithics and pyrite;porosity and permeability visually good; no oil indicators. 13 3/8 SCP @ 2334.7' MD/-2107.2' TVDSS TD 13 3/8" BOREHOLE 2347.0" MD/-2116.4'TVDSS Sand (2370-2460') = medium light gray to medium gray; upper fine to lower medium grains; spherical to subdiscoidal;angular to subangular;well to moderately well sorted;sand is unconsolidated;grain supported; texturally immature;compositionally immature;translucent to translucent with faint yellow quartz;glauconite, muscovite,and carbonaceous material present;carbonaceous material exhibits thin laminations;porosity and permeability visually good. no oil indicators. Sand(2460-2520)=medium gray to medium light gray; upper fine to lower medium grained;subdiscoidal to spherical; subangular to angular; moderately well to well sorted; sand is unconsolidated; grain supported; compositionally immature;texturally immature;translucent quartz with glauconite,and pyrite; carbonaceous siltstone with carbonaceous silt material and carbonaceous material in laminations; porosity/permeability visually good; no oil indicators. Carbonaceous Shale(2520-2570')=black to brownish black to reddish brown; soft to hard;tough dense to brittle and crunchy;planar to sub-blocky fracture;tabular to platy cuttings habit; resinous vitreous when wet to dull and earthy and slightly waxy luster when dry; matte texture; no visible structures. Sand(2520-2670')=clear to translucent to smoky to light gray with green and brown hues throughout sample interval; upper medium to upper very fine; poor sorting; angular to subangular with low sphericity; unconsolidated sand grains; muscovite sheet fragments scattered throughout sample interval, approx 3%; pyrite occurs both as disseminated grains and as crystal growths on surface of other minerals within samples, approximately 3-5%; brilliant green to moderate green glauconite throughout, approx 5-6%; no oil present. Sand (2670-2730') = translucent to milky white to light gray to clear with green and brown hues; upper medium to lower fine; poor sorting; angular to subangular; low to moderate sphericity; unconsolidated sand grains; scattered muscovite sheet fragments throughout sample interval, vitreous opalescent sheen; pyrite grains disseminated throughout sample interval, also crystal growths on and within quartz grains; moderate green to brilliant green glauconite; no oil present. 13 CAIRIG eni 0111-01 and PB1 Sand (2730-2820')=translucent to light gray to milky white to clear to smokey with brown to greenish hues throughout sample interval; upper medium to lower fine; poorly sorted; low to moderate sphericity; unconsolidated sand grains;muscovite sheet fragments scattered in samples;pyrite occurs both as individual grains and as crystalline growths on and within other minerals in samples; moderate green to bluish green glauconite; no oil present. Carbonaceous Shale(2790-2820') = black to reddish brown to brownish black to moderate brown; soft to hard, depending on maturity; soft cuttings are malleable and hard cuttings are crunchy brittle to tough and dense; sub-blocky to planar fracture; tabular to platy cuttings habit; vitreous resinous to earthy dull luster; clayey to matte texture; thin black to reddish brown laminations in some cuttings. Uonu-2 Coal Bed Marker 2818.1' MD/-2429.7'TVDSS Sand (2820-2940') = clear to light gray to translucent go milky white with brown and greenish hues; upper medium to upper very fine; poorly sorted; angular to subangular; low to moderate sphericity; unconsolidated sand grains predominantly with some clumps held together by clayey matrix; approximately 5% muscovite sheet fragments throughout sample interval,white opalescent sheen;approximately 5%pyrite occurring both as individual grains and as crystalline growths on other mineral surfaces; moderate green to brilliant green glauconite; no oil present. Sand (2940-3000') = milky white to clear to translucent to smoky to medium light gray with brownish hues; upper medium to lower fine;poor sorting;subangular to angular with moderate to low sphericity;predominantly unconsolidated sand grains with some clumps held together by clayey matrix; approx 5%white opalescent muscovite sheet fragments; approx 5% pyrite both as crystalline growths and as individual disseminated grains; brilliant green to bluish green glauconite, approx 5%; no oil present. Sand (3000-3090) = translucent to light gray to medium light gray to milky white with some greenish hues throughout sample interval; predominantly lower fine to upper medium with occasional upper very fine and coarse grains;poor sorting;angular to subangular with low sphericity;mostly unconsolidated sand grains with few clumps of sand bonded with clay;white opalescent muscovite sheet fragments throughout sample interval; pyrite occurs both as individual grains and as crystalline growths on the surfaces of other minerals; brilliant green to moderate green glauconite; no oil present. Sand (3090-3180) = clear to light gray to translucent to milky white with brown and greenish hues; upper medium to upper very fine; poorly sorted;angular to subangular; low to moderate sphericity; unconsolidated sand grains predominantly with some clumps held together by clayey matrix; approximately 2% muscovite sheet fragments throughout sample interval,white opalescent sheen;approximately 3%pyrite occurring both as individual grains and as crystalline growths on other mineral surfaces; moderate green to brilliant green glauconite; no oil present. Sand (3180-3270') = medium dark gray to medium gray with olive gray sub tones; upper medium to lower medium grains with occasional upper fine to lower fine grains; spherical to subdiscoidal; subangular to angular;moderate to poor sorting;unconsolidated sand;grain supported;texturally immature;compositionally immature; translucent to milky white quartz sand with green glauconite, pyrite and carbonaceous material; pyrite appears as both disseminated and as overgrowths on grains as well as glauconite;carbonaceous shale is black to brown with reddish sub-hues,at time exhibits thin laminations with two grain thicknesses of quartz beds between carbonaceous laminations, planar fracture; gray chert also present; porosity and permeability visually good; no oil indicators. Sand (3270-3390') = medium gray to medium dark gray with olive gray to light olive gray sub hues; lower medium to upper fine with some lower fine grains; spherical to subdiscoidal;angular to subangular rounding; moderate to moderately poor sorting; unconsolidated sand; grain supported; immature texturally; immature compositionally;translucent and milky white quartz with chert,pyrite,glauconite and carbonaceous shale/silt; chert is gray to black, lower medium to upper fine, subangular, subdiscoidal; green glauconite; pyrite encrusted glauconite/chert and disseminated pyrite;carbonaceous silt/shale only in first 30'of interval;porosity and permeability visually good; no oil indicators. 14 rAw� xRG eni 0111-01 and PB1 Carbonaceous Clay/Silt(3390-3420')=brownish gray with olive gray sub-tones;soft; poorly to very poorly indurated; flexible to elastic tenacity; earthy fracture; massive cuttings habit; waxy to dull to earthy luster; clayey to silty texture; massive observed structure; carbonaceous material of silt size mixed with clay/silt; carbonaceous siltstone black, brownish black with reddish brown streaks, can be inferred to be interbedded with clay; no oil indicators. Sand (3420-3480') = medium dark gray to dark gray; upper fine to lower medium grained; spherical to subdiscoidal; angular to subangular; moderately sorted; unconsolidated sand; texturally immature; compositionally immature;translucent quartz;abundant disseminated pyrite;porosity and permeability visually good; no oil. Clay(3450-3480') =olive gray to medium olive gray; soft; poorly to very poorly indurated; flexible to elastic tenacity;earthy fracture;massive cuttings habit;dull to earthy luster;clayey texture; massive structure; no oil indicators. Sand (3480-3600') = medium dark gray to dark gray; upper fine grains with occasional lower medium and lower fine grains; spherical to subdiscoidal; angular to subangular; moderately well sorted; unconsolidated sand;texturally immature;compositionally immature;grain supported;translucent to milky white quartz; light green glauconite, gray and black chert, and disseminated pyrite; porosity and permeability visually good; no oil. Sand (3600-3690') = medium light gray to medium gray to medium dark gray with a salt and pepper appearance at beginning of interval; lower medium to upper fine with occasional lower fin grains;spherical to subdiscoidal; angular to sub-rounded; moderately sorted; unconsolidated sand; grain supported; texturally immature; compositionally immature; translucent and milky white quartz; accessories include: light green glauconite,black chert and pale yellowish orange lithics;small amounts of light gray clay with entrained sand; porosity and permeability visually good; no oil. Sand(3690-3810')=medium dark gray to medium light gray with olive gray sub tones;lower medium to upper fine grains with occasional lower fines;spherical to subdiscoidal;angular to subangular rounding;moderately to moderately well sorted; unconsolidated sand; texturally immature; compositionally immature; translucent and milky white quartz; accessories include light green glauconite, black and gray chert, chlorite and disseminated pyrite;chert is upper fine,spherical,and angular; reddish black carbonaceous material with thin laminations; porosity and permeability visually good. no oil indicators. Sand(3810-3900')=medium dark gray to medium gray with salt and pepper appearance;upper fine to lower medium grains with some lower fines; spherical to subdiscoidal; angular to subangular; moderate to moderately well sorted; unconsolidated sand;grain supported;texturally immature;compositionally immature; translucent and milky white quartz;black,brown and gray chert, light green glauconite,muscovite,chlorite and reddish brown lithics;clays going into solution,clay is gray,soft,poorly indurated,cohesive,gelatinous,elastic tenacity,massive cuttings habit,dull luster,clayey texture,massive structure; interpreted as interbedded with sand; porosity and permeability visually good; no oil indicators. Sand (3900-3990') = medium dark gray to dark gray with olive gray sub tones and salt and pepper appearance; lower medium to upper fine grains with some lower fines; spherical to subdiscoidal; angular to subangular;moderately to moderately well sorted;unconsolidated sand;grain supported;texturally immature; compositionally immature; translucent and milky white quartz grains; black and gray chert, lower medium, upper fine,subdiscoidal,subangular; light green glauconite,upper fine,sub-rounded,subdiscoidal;upper fine, black carbonaceous material; porosity and permeability visually good; no oil indicators. Clay(3990-4080')=olive gray to light olive gray;soft;poorly to very poorly indurated;cohesive,adhesive clay; slimy to tacky consistency; elastic to flexible tenacity; earthy fracture; massive cuttings habit; earthy to dull luster;clayey to silty texture;massive observed structure;sand grains entrained with in clay,most likely due to reworking by bit; no oil indicators. 15 CAIRIG eni 0111-01 and PB1 Sand(3990-4110')= medium gray to medium dark gray; upper fine to lower medium grains; subdiscoidal to spherical;angular to subangular;moderate to moderately well sorted; unconsolidated sand;grain supported; texturally immature;compositionally immature;translucent and milky white quartz;black and gray chert,upper fine grain, subdiscoidal, subangular; disseminated pyrite and pyrite encrusted sand grains; light green glauconite; porosity and permeability visually good; no oil indicators FAULT#1 NOT FOUND ON LOGS Sand (4110-4200) = medium dark gray to medium gray with translucent quartz grains yielding a salt and pepper appearance; spherical to subdiscoidal; angular to subangular; moderate to moderately well sorted; unconsolidated sand; grain supported; immature texturally; compositionally immature;translucent and milky white quartz; light green glauconite; black and gray chert; pale yellowish orange lithics; muscovite; disseminated pyrite; porosity and permeability visually good; no oil. Sand (4200-4290) = olive gray to light olive gray, salt and pepper appearance; upper fine to lower medium grains;spherical to subdiscoidal;angular to subangular;moderate to moderately well sorted; unconsolidated sand; grain supported; texturally immature; immature compositionally; translucent and milky white quartz; disseminated and grain incrusted pyrite; light green glauconite;clay,medium light gray,poorly indurated,soft, cohesive, tacky consistency, elastic tenacity, earthy fracture, massive cutting habit, earthy luster, clayey texture, massive structure; black to dark brown carbonaceous material; porosity and permeability visually good; no oil. Clay(4290-4380')=olive gray to light olive gray;soft;poorly to very poorly indurated;cohesive and adhesive; slimy to tacky consistency;elastic to stiff tenacity;earthy fracture;massive cuttings habit;dull to earthy luster; clayey to smooth texture; massive visible structure,entrained sand interpreted as thin beds; non reactive with HCI; sand entrained within clay; sand,translucent quartz and black, gray chert, upper fine to lower medium, spherical to subdiscoidal,angular to subangular,moderate sorting,unconsolidated,grain supported,texturally immature, compositionally immature; no oil. Sand (4380-4440') = medium dark gray to olive gray; upper fine to lower medium grains; spherical to subdiscoidal; angular to subangular; moderate sorting; unconsolidated sand; grain supported; texturally immature; compositionally immature; translucent and milky white quartz; carbonaceous shale, black with reddish brown streaks, planar fracture; porosity and permeability; no oil indicators. Clay (4440-4500') = olive gray to light olive gray with medium to medium light gray sub-tones; cohesive, adhesive, and plasticity; lumpy, tacky and slimy consistency; flexible to elastic tenacity; earthy fracture; massive cuttings habit;dull to earthy luster; clayey to silty texture;massive observed structure;carbonaceous material, reddish brown with laminar bedding; no oil indicators. Clay(4500-4560')=olive gray to light olive gray;cohesive, adhesive and plastic; lumpy to clumpy and slimy to tacky consistency; stiff to elastic to flexible tenacity; earthy fracture; massive cuttings habit; dull to earthy luster; clayey to smooth texture; sand entrained within clay and loose; sand, translucent and milky white quartz, upper fine,subdiscoidal,angular,moderately sorted;texturally immature;compositionally immature;no oil indicators. LOWER UGNU 4612.0 MD/-3129.3 TVDSS Sand/Conglomeratic Sand (4560-4680) = medium light to medium gray with a slight brownish secondary hue; moderately to poorly sorted; medium lower to fine upper and coarse with occasional small 2 to 3mm pebbles and larger pebble fragments; angular to sub -angular in finer material; coarse tends to be slightly rounded; predominantly trans-lucent white to light gray quartz with abundant medium to light brownish gray chert and lithics; trace glauconite, limonite and pyrite; trace to common gray-white ash as matrix material; trace dead oil stain with a dull greenish yellow fluorescence and slight cut; slightly calcareous. Sand/Conglomeratic Sand(4680-4710')=dark gray to grayish black; upper very coarse to lower medium, predominately upper to lower coarse; spherical to subdiscoidal; sub-rounded to rounded chert, angular to 16 CA11A21G eni 0111-01 and PB1 subangular quartz; poorly sorted; unconsolidated sand, consolidated sandstone; siliceous cement; grain supported and matrix/cement supported quartz sandstone; texturally immature; compositionally immature; grayish black to gray and bluish green chert,chert is both angular and rounded,angular chert has conchoidal fractures; translucent and milky white quartz; quartz sand also contains disseminated pyrite, black carbonaceous material and black chert;quartz sand exhibits light, 10%faint brown stain;very faint dark brown fluorescence cut; clear cut; no residual fluorescence cut; no oil odor; porosity and permeability visually poor. Sand (4710-4890') = dark gray to medium dark gray with salt and pepper appearance; upper fine to lower medium grained;spherical to subdiscoidal;angular to subangular;moderately to moderately well sorted;grain supported;texturally immature;compositionally immature;sand is unconsolidated;translucent and milky white quartz, black and medium to dark gray chert; pale yellowish orange lithics, light green lithics,glauconite and pyrite;pyrite increases as interval increases,some grain incrusted pyrite,mostly disseminated pyrite;porosity and permeability visually poor; no oil. Sand/Sandstone/Conglomeratic Sand (4890-5010') = medium to medium light gray with a distance brownish secondary hue;well to locally poorly sorted;friable in part;fine upper to medium lower predominate; scattered to locally abundant medium upper to coarse and small pebbles and pebble fragments; angular to subangular in the finer material;coarser material tends to be slightly rounded to subangular;abundant angular pebble fragments;translucent white to gray and clear colorless quartz predominate;20 to 30%medium to light and dark gray quartzite,chert and lithic grains;very abundant medium to dark brownish gray lithics and chert grains; trace glauconite; trace orange and mottled orange and brown jasper; trace rewelded fault gange; abundant pyrite;trace hard angular sandstone flakes; moderately calcareous;trace medium brown dead oil stain; very slight dull yellow crush cut; no visible residue, no oil odor. Sand(5010-5100')=medium gray with a slight brownish secondary hue;sample collected as disaggregated loose sand; moderately well sorted; medium upper to coarse lower grain; trace coarse upper; subangular to sub-rounded and angular;translucent white, light gray and clear colorless quartz predominate; abundant to 30% dark to medium gray and brownish gray lithics/chert; common dark gray to black lithic/mafic mineral grains; trace coal fines; trace to abundant pyrite; trace glauconite stained quartz; trace orange jasper; no matrix material or; no well cemented sandstone fragments noted; slight crystal over-growth visible on some grains; slightly calcareous; no oil indicators. Sand(5100-5240')=medium gray with a slight brownish secondary hue;sample collected as disaggregated loose sand;well sorted;medium upper to fine upper trace coarse grain;subangular to angular to sub-rounded; translucent white, light gray and clear colorless quartz predominate; abundant to 30% dark to medium gray and gray-brown lithics; abundant brownish gray and brown chert; abundant glauconite stained grains and occasional green glauconite; abundant coal fines;common pyrite as small masses and as inclusions in lithic grains; 10%of material is matrix supported, soft, moderately indurated fine grain quartz sandstone; matrix is very light brownish gray ash/clay; trace orange jasper; no oil odor, trace very slight oil stain on some fragments; no notable fluorescence or cut; very slightly calcareous. SCHRADER BLUFF 5178.2 MD/-3332.7'TVDSS TO 6007'MD/-3601.2'TVDSDS Drill Rate(ft/hr) Total Gas(units) Maximum Minimum Average Maximum Minimum Average 417 16.4 5428 659 4 97.7 PEAKS Depth TG C1 C2 C3 C4I C4N C5I C5N 5187 21 4440 7 16 14 33 12 0 5228 49 9930 26 0 0 12 15 0 5415 281 55706 655 177 243 101 172 32 5479 262 46085 593 134 87 26 46 21 5595 376 63718 905 _ 243 220 68 253 21 5700 73 10836 _ 150 57 84 46 141 13 17 CANEIG eni 0111-01 and PB1 5872 36 5932 84 72 57 70 20 56 5897 659 104083 1716 1651 1142 1469 896 601 5977 326 51731 876 787 530 650 403 254 The Schrader Bluff formation is the zone of interest in this well. At this location, it consists of two main sands, the"N"Sand and the"0"Sand. The Schrader Bluff is an Upper Cretaceous turbidite deposit formed as sand lobes. In general, the"OA" Sands contain viscous crude with an API gravity between 16°and 19°. The"N" Sand was encountered at 5178'MD, its contact with the overlying Ugnu,fault#1 was not identified from MWD logs, however sedimentary evidence of a fault was seen in the 5010' MD sample. Sand (5240-5310') = medium gray with a slight brownish secondary hue; disaggregated; friable in part; moderately sorted; medium lower to medium upper and coarse with scattered shattered angular pebble fragments/flakes;angular to sub-rounded;dark gray to gray-brown lithics predominate;40%translucent white to light gray quartz; lithics;abundant dark brown to gray chert;trace glauconite;trace to common small pyrite masses; common coal fines; common dark mafic mineral/lithic grains; occasional trace orange chert, trace blue-gray and brown lithics;trace ash/clay matrix sandstone and coal fines;trace very light tan calcite;slightly calcareous; no oil indicators. Sand/Sandstone(5310-5430')=medium to medium light gray with a pronounced brownish secondary hue; firm to soft and disaggregated; moderately well sorted; medium lower to fine upper and medium upper grain; occasional coarse; common to trace very fine grain angular moderately hard sandstone fragments; subangular to slightly rounded;all supported in soft light brownish gray matrix;occasional cleaner loose sand suggests at least partial grain support; matrix is soft hydrophilic ash/clay;moderately cohesive;non adhesive; individual grains are predominantly light smokey gray to translucent white and clear colorless quartz; 30 to 40% light to medium gray and brownish gray lithics; trace blue-gray and orange grains; common to trace pyrite; slight oil stain begins at 5370'sample and increases through the zone;visible oil at the shakers and in samples after 5370 moderate oil odor;20 to 50%oil stain;20 tO 100%dull gold sample fluorescence with fast streaming cut to milky medium bright blue-white; good medium gold residue cuts immediately to blue-white; slightly calcareous. N SAND TOP 5403.0' MD/-3413.1' TVDSS N SAND BASE UNIT TOP 5516.0' MD/-3456.2'TVDSS Sand/Conglomeratic Sandstone (5430-5610') = medium to medium light gray with a moderate brownish secondary hue;soft to disaggregated; moderately well to poorly sorted;medium lower to fine upper in the top of the zone grading to medium upper to coarse lower and medium lower with scattered to abundant very coarse and occasional small pebble fragments; trace very fine grain clean angular and sub-rounded; predominantly translucent light gray/smokey and white quartz;common clear colorless quartz;30-40%light to medium and dark gray/gray brown lithics; common to abundant light blue-gray lithics; common to abundant pyrite; trace orange jasper; trace tan to off white shell fragments; occasional very thin coal interbeds; 10 to 40%visible oil stain; slight oil odor; 30 to 90%dull gold fluorescence;fast streaming cut to blue-white; good medium gold residue cuts immediately to blue-white; slightly calcareous. Sand/Conglomeritic Sand (5610-5700') = medium dark gray to medium gray with grayish black to black speckles; lower medium to lower coarse grains with occasional upper very coarse grains; subprismoidal to subdiscoidal sphericity; angular to subangular; moderately to poorly sorted; unconsolidated sand; grain supported;texturally immature;compositionally immature;translucent and milky white quartz;grey and black chert, light green glauconite, green lithics, pale yellowish orange shell fragments, black to brownish black carbonaceous material with laminations and disseminated pyrite; slight oil odor;trace stain light brown stain 5%;sample fluoresces 50%patchy bright,straw yellow;clear to light brown cut; no residual cut; bright bluish white residual cut; light brown to dark brown free oil collecting at the end of the shakers;free oil in clays within sample; porosity and permeability visually good. �•��p� 18 CAN RIG ilaK eni 0111-01 and PB1 Sand (5700-5795') = medium dark gray to dark gray; lower medium to lower coarse; subprismoidal to subdiscoidal; angular to subangular; moderate sorting; unconsolidated sand; friable sandstone; matrix supported;siliceous matrix;textural/compositionally immature;translucent quartz,gray chert; lithics;no odor; no stain; fluorescence 30% dull yellow; thin bluish white fluorescent cut; no visual cut; faint white residual fluorescence; no residual cut. Carbonaceous Shale (5795-5820') = gray black to black; firm friable; moderately hard; blocky fracture; tabular cutting habit;greasy luster; laminar structure;sample contaminated with SafeCarb mud additive; no oil indicators. Sand(5820-5860')=medium dark gray to grayish black; upper fine to lower medium;spherical to subdiscoidal angular to sub-rounded;moderate sorting unconsolidated;quartz and chert grains;faint brown fluorescence; no odor; light bluish white stream cut; light brown cut; clear residual;faint light brown residual fluorescence. Siltstone(5860-5685')= medium dark gray to medium gray; soft; poorly indurated; massive cuttings habit; silty texture; no discernable structure; no odor; even light yellow fluorescence; streaming bluish white fluorescence cut; clear cut; no residual cut. OA SAND TOP 5874.0' MD/-3572.9'TVDSS Sand (5985-6013') = olive gray to light olive gray; upper fine to lower fine, occasional lower medium; subprismoidal to subdiscoidal; angular to subangular; moderately to moderately well sorted; unconsolidated sand; grain supported;translucent quartz; light green lithics, disseminated pyrite and pale yellowish orange shell fragments; strong oil odor; 50% grains dark brown stain; 75% sample fluoresces bright yellow gold; immediate blooming bright white fluorescent cut;light amber cut;light brown residual cut;bright white residual fluorescence; free oil on shakers and in possum belly. SCHRADER BLUFF LATERAL SECTION 6007' MD/-3600.1'TVDSS TO FINAL TD AT 10594' MD/-3634.4' TVDSS Drill Rate(ft/hr) Total Gas(units) Maximum Minimum Average Maximum Minimum Average 394.4 11.4 196.9 672 20 205.1 PEAKS Depth TG C1 C2 C3 C4I C4N C5I C5N 6125 535 86036 689 251 120 128 59 38 6201 673 102870 903 332 159 162 82 58 6305 639 98491 907 331 158 163 84 50 6342 607 97378 8896 328 148 151 74 51 6488 629 102937 952 429 247 284 137 91 6591 595 113945 1057 449 261 311 173 111 6693 523 86796 778 362 223 281 169 116 6769 401 79188 684 299 167 182 102 60 6820 324 63900 535 244 140 159 93 56 6973 316 61507 534 257 158 187 127 93 7107 380 81947 685 292 183 226 130 94 7438 380 73265 588 198 135 155 115 72 7820 472 97165 696 174 129 171 116 102 7918 475 88016 704 152 148 185 110 122 8168 455 84211 673 146 142 177 105 117 8246 458 97100 773 171 153 195 119 122 8306 472 100218 794 182 141 187 119 106 8696 _ 541 76179 3478 3096 2869 3184 3592 4936 19 CANR K] eni 0111-01 and PB1 8792 450 87621 648 153 125 151 98 108 9033 369 74335 550 132 102 145 93 86 9328 410 83083 567 121 97 116 88 77 9863 464 94906 655 151 116 162 129 112 9984 512 104503 728 _ 164 127 177 152 119 10573 369 89389 651 177 169 233 221 195 Sand/Sandstone (6007-6180') = medium light gray with a slight brownish secondary hue; friable; sample collected as loose disaggregated sand with scattered sandstone fragments; angular to subangular; medium lower to medium upper predominates; scattered coarse lower and very fine upper; trace coarse upper and larger fragments; primarily translucent white to light gray quartz; 30 to 40% medium to light gray lithics; trace to common dark gray to black lithic/mafic mineral grains;trace orange jasper;trace gray green and green glauconitic grains;common light to medium tan shell fragments;note;common medium brown waxy resilient, slightly sandy claystone;samples contaminated with SafeCarb;very calcareous; general NAF fluorescence; 30 to 60%medium yellow sample fluorescence;fast streaming cut to yellow-white;good brown residue ring with dull gold fluorescence cuts to yellow-white; NAF odor; occasional slight stain. OA SBL-3 6318.0 MD/-3614.1 TVDSS Sand/Sandstone (6180-6330) = medium light gray with a slight brownish secondary hue; friable in part; samples collected as irregular angular to slightly rounded sandstone fragments and loose sand;medium lower to fine upper with common medium upper; loose sand tends to be larger grain with occasional coarse lower grains; angular to sub-angular in the finer fraction; larger grains tend to be slightly rounded to angular; primarily translucent white to light gray and clear quartz; trace orange jasper and blue-gray lithics; trace glauconite;abundant to 20%light tan shell fragments;trace fine grain carbonaceous inclusions; interbedded with medium brown waxy, resilient sandy claystone and occasional carbonaceous shale; very calcareous; contaminated with safe-carb;general obm fluorescence becoming more yellow with formation oil;20 to 100% dull yellow sample fluorescence; fast streaming cut to yellow-white; good brown residue ring with dull gold fluorescence cuts to yellow-white; trace stain; obm odor. FAULT#1 11-01 6370.0 MD/-3613.7 TVDSS Siltstone (6330-6420) = medium light gray; slight brownish secondary hue in part; firm to hard; irregular angular cuttings habit; silty to gritty texture dull earthy to grainy luster; thinly laminated; trace to abundant carbonaceous micro-lamina; common fine carbonaceous inclusions; trace pyrite; samples also include moderate amounts of similar silty sand and occasional oil saturated fine to medium grain sandstone; trace pyrite;trace shell fragments; 100%obm fluorescence;20%medium yellow bleeding from fragments into base oil wash; sandstone yields fast streaming yellow-white cut as previously described. Sandstone/Silty Sandstone(6420-6570)=medium light to light gray;firm to hard;slightly friable;moderately well sorted;fine upper to fine lower and medium lower;vertically sorted; moderately to very silty;sub-rounded to sub-angular, angular and sub spheroidal primarily translucent white to light gray quartz; 40% light to medium gray lithics;trace rounded white grains are possibly fossils;trace dark gray to black grains;trace coal fines and carbonaceous micro-lamina in silty material;trace to abundant shell fragments;trace orange jasper and pyrite;trace medium blue-gray lithics;primarily grain supported in the sandstone with variable amounts of silt as matrix;30-70%yellow sample fluorescence bleeding from sandstone cuttings;strong obm odor;30-50% visible brown oil staining present;fast streaming yellow white cut fluorescence;dark amber to brown streaming visible cut; dull amber to dark amber visible residue; dull yellow residual fluorescence. OA SBL-2 6678.0 MD/-3618.6 TVDSS Sandstone(6570-6720)= light gray to medium light gray to medium gray throughout sample interval; lower fine to upper very fine to trace upper fine grained;well to moderately well sorted;sub-rounded to sub-angular with few angular grains; moderate to high sphericity; firm to moderately hard to trace friable cuttings; Aw�'r 20 CANRK3 eni. 0111-01 and PB1 disaggregated;predominantly translucent milky white to transparent to light gray quartz;trace grayish green to pale bluish green lithics;trace pyrite as growths on other grains;50%dull yellow sample fluorescence;20-30% dark brown oil staining;obm odor;slow streaming milky white cut fluorescence;slow streaming amber visible cut;dull light brown visible residue;dull yellow residual fluorescence;moderately to very calcareous;possibly safe-carb additive. Sandstone/Silty Sandstone(6720-6870)= medium light to light gray to medium gray overall; moderate to moderately well sorted;firm to hard to slightly friable;upper fine to lower fine to lower medium;moderately silty in part; sub-rounded to sub-angular to angular; high sphericity; light gray to translucent white quartz predominates; very thin micro-lamina present on smooth side of silty sandstone cuttings; trace pale grayish green to bluish gray glauconite; looks to be grain supported in sandstone cuttings to matrix supported in cuttings with increase in silt content; 40-70%yellow sample fluorescence; strong obm odor; 30-50%visible brown oil staining;streaming yellow white cut fluorescence;streaming brown visible cut;brown visible residue fluoresces dull yellow. Sand/Sandstone(6870-6960) = medium light to light gray to medium gray; lower fine to upper very fine to upper fine grained; moderately well to well sorted; sub-rounded to sub-angular with moderate sphericity; disaggregated; friable to firm; predominantly clear colorless to transparent milky white to slightly smokey quartz;trace moderate blue green to brilliant green glauconite;5%orangish pink to pale yellowish orange shell fragments;abundant very fine grained dark brown/black lithics giving a salt and pepper appearance;60-90% dull yellow sample fluorescence; strong obm odor; slow streaming bluish yellow cut fluorescence with slow light amber to straw visible cut; straw to light amber visible residue; faint yellow residual fluorescence; non- calcareous besides shells. OA SBL-2 6962.0/-3624.6 TVDSS Siltstone/Sandy Siltstone(6960-7050)=light gray to medium light gray with slight brownish secondary hue; very fine grained to lower fine grained in sandy cuttings; firm to hard to friable in part; dense brittle tenacity; irregular fracture; angular wedge like cuttings habit; earthy dull to waxy luster; silty gritty texture; trace coal fines and carbonaceous micro-lamina;5%orangish pink to pale yellowish orange shell fragments increasing to 10%with depth with some as large as 5mm; trace moderate green to brilliant green fine grained lithics; 30- 40% bleeding dark brown oil staining in sandstone cuttings; 30-50% dull yellow sample fluorescence; dull yellow-white cut fluorescence;light amber to straw visible cut;strong obm odor;faint light straw to straw visible residue; faint yellow residual fluorescence. Sandstone(7050-7170)=light to medium light gray with slight green secondary hue; lower fine to upper very fine to trace upper fine; well to moderately well sorted; sub-rounded to sub-angular; high sphericity; disaggregated;firm to friable;abundant brilliant green to moderate blue green glauconite;abundant very fine dark brown/black lithics gives salt and pepper appearance;20-40%visible dark brown oil staining;strong obm odor;30-50%even yellow sample fluorescence;fast streaming milky yellowish white cut;streaming amber to light brown visible cut; medium dark straw to light amber visible residue;dull yellow residual fluorescence; no reaction with HCI. Sandstone(7170-7290)=medium light to light gray with slight green secondary hue;lower fine to upper very fine to trace upper fine;well to very well sorted; sub-rounded to sub-angular; high sphericity; disaggregated; predominantly translucent milky white to transparent to light gray quartz;abundant pale green to brilliant green to moderate blue green glauconite; abundant very fine to dark brown/black lithics gives a salt and pepper appearance;trace pyrite and very fine grained orange lithics;trace orangish pink to pale yellowish orange shell fragments; strong obm odor; 10-20%visible light brown oil staining; 100%even dull yellowish white sample fluorescence; faint dull yellow to slow milky white cut fluorescence; slow streaming amber to dark amber visible cut; light to medium straw visible residue; dull yellow residual fluorescence. 21 CANRI] Cnl 0111-01 and PB1 OA SBL-3 7365.0 MD/-3635.6 TVDSS Sandstone/Silty Sandstone(7290-7440)= light gray to medium light gray to medium gray with secondary brownish hue; lower fine to upper very fine to upper fine; sub-rounded to sub-angular to angular in part; moderately to high sphericity;firm to hard to friable; predominantly grain supported in the sandstone cuttings to a more silty matrix with increase in silty material;predominantly translucent milky white to light gray to clear colorless quartz; scattered to trace pyrite and orange lithics present;trace to abundant pale green to brilliant green glauconite; trace to abundant dark brown to black lithics; scattered pale yellowish orange to orangish pink shell fragments;thin micro-lamina visible on smooth side of silty cuttings; strong obm odor present;20- 40% light brown visible staining in sandstone cuttings; 30-60% patchy bright yellowish white sample fluorescence; slow streaming dull yellow white cut fluorescence; slow streaming light straw to dark straw visible cut; faint light straw to straw visible residue; faint yellow residual fluorescence; no reaction with HCI. Sandstone(7440-7620)= light gray to medium gray with secondary brownish hue; lower fine to upper very fine to trace upper fine; well to moderately well sorted; sub-rounded to sub-angular to angular in part; moderate to high sphericity; disaggregated; firm to hard to friable; predominantly translucent milky white to light gray to clear colorless quartz; light brownish gray to brownish gray silty sandstone/sandy siltstone increases with depth of interval; abundant pale green to brilliant green to moderate blue green glauconite; abundant very fine to dark brown/black lithics gives a salt and pepper appearance;trace pyrite and very fine grained orange litchis; 5-10%orangish pink to pale yellowish orange shell fragments within sample interval; strong obm odor; 10-20% light brown visible oil staining; 70-90% dull yellow to bright white sample fluorescence;blooming milky yellowish white cut fluorescence;fast streaming dark amber visible cut;medium dark straw to amber visible residue; dull yellowish white residual fluorescence; slightly calcareous. FAULT#211-01 7636.0 MD/-3648.2 TVDSS Siltstone/Sandy Siltstone(7620-7710)=medium gray to medium dark gray;firm to very firm;sandy/gritty to silty texture; gritty to dull earthy luster; contains common to abundant to trace amounts of fine lower to very fine grain sand; no apparent fissility; widely disseminated very fine carbonaceous material; trace micro-thin carbonaceous lamina;abundant to 10%tan shell fragments;trace sandy ash/clay; included sand is primarily very fine upper to fine lower grain; trace medium, moderately well rounded and in similar mineralogical distributions as the associated sandstone; overall the material is very slightly to trace calcareous; shell fragments are very calcareous;trace oil stain in some fragments;general obm fluorescence medium yellow oil fluorescence on sandy fragments and some siltstone with fast streaming cut to yellow-white;brownish residue fluoresces dull gold and cuts readily to yellow-white. OA SBL-1 7760.0 MD/-3656.5 TVDSS Siltstone/Sandy Siltstone(7710-7800)=medium gray to medium dark gray;firm to very firm;sandy/gritty to silty texture;gritty to dull earthy luster;contains common to trace amounts of fine lower to very fine grain sand; no apparent fissility;widely dispersed very fine carbonaceous material;trace micro-thin carbonaceous lamina; abundant to 10% tan shell fragments; included sand is very fine upper to fine lower grain; trace medium, moderately well rounded and in similar mineralogical distributions as the associated sandstone; overall the material is very slightly to trace calcareous; shell fragments are very calcareous; trace oil stain in some fragments;general obm fluorescence medium yellow oil fluorescence on sandy fragments and some siltstone with fast streaming cut to yellow-white; brownish residue fluoresces dull gold and cuts readily to yellow-white. Sandstone/Silty Sandstone(7800-7950) = medium light to medium gray; firm to disaggregated and hard; friable in part;samples consist of irregular moderately to slightly silty sandstone and variable amounts of loose sand; moderately well sorted; very fine upper to fine lower and medium lower grain; sub-rounded to sub- angular and sub-spheroidal; primarily translucent light gray to white quartz sand; 30 to 40% light to medium gray lithics;scattered to common dark mafic mineral/lithics;common to abundant glauconite and pyrite;trace to scattered orange jasper; trace oil staining in cuttings; dull to medium yellow oil fluorescence on sandy cuttings; fast streaming cut to dull yellow; dull gold residual fluorescence from brownish residue. 22 CAtIG eni 0111-01 and PB1 OA SBL-2 7990.0 MD/-3663.2 TVDSS Siltstone (7950-8070) = medium gray to medium light gray to medium dark gray; firm to very firm; dense tough tenacity; irregular fracture; dull earthy slightly waxy luster; silty to gritty texture; abundant to trace amounts of lower fine to very fine grain sand; widely disseminated very fine carbonaceous material; trace micro-thin carbonaceous lamina;trace to common tan shell fragments;trace sandy ash/clay; included sand is primarily very fine upper to fine lower grain; trace medium, moderately well rounded and in similar mineralogical distributions as the associated sandstone; overall the material is very slightly to trace calcareous; shell fragments are very calcareous; trace oil stain in some cuttings; general obm fluorescence faint golden yellow oil fluorescence on sandy fragments and trace on siltstone;streaming cut to yellow-white with streaming amber visible cut; brown residue fluoresces dull yellow. Siltstone(8070-8200)=medium gray to medium dark gray with secondary brownish hue;friable to firm;brittle to dense tenacity; irregular fracture nodular cuttings habit; earthy dull luster; silty to gritty texture; thin carbonaceous micro-lamina visible; abundant to trace amounts of lower fine to very fine grain sand;trace to common orangish pink to pale yellowish orange shell fragments; included sand is primarily upper very fine to lower fine grained;overall the sample is very slightly to trace calcareous except for shell fragments which are very calcareous;trace oil staining in trace sandstone cuttings; mainly obm fluorescence with faint dull golden yellow oil fluorescence on sandstone cuttings; fast streaming dull yellow white cut fluorescence; streaming amber visible cut; light amber residue fluoresces dull golden yellow. OA SBL-3 8204.0 MD/-3671.5 TVDSS Siltstone(8200-8280)= light gray to medium light gray to medium gray; overall dense ranging from stiff and tough to crumbly and brittle;irregular fracture;elongated round nodule shape cuttings habit;dull earthy luster; generally gritty to silty texture or granular and gritty; mix between grain supported and clay matrixes;very fine upper to lower fine sand grains;well sorted;sub-angular to sub-round;glauconite presence ranging from trace amounts to fairly abundant;occasional oil staining in nodules and exhibit a light orange fluorescence and slight yellowish orange cut amongst the obm contamination. Siltstone(8290-8370)=light gray to medium light gray to medium dark gray;dense tough tenacity;friable to moderately hard; irregular fracture; elongated nodular cuttings; dull earthy to waxy luster; clayey to silty to gritty texture; loose unconsolidated sand; upper very fine to lower fine; mostly translucent;fair to well sorted; sub-round to sub-angular;grain supported matrix;trace oil stain in some cuttings general obm fluorescence; faint golden yellow oil fluorescence on sand fragments and trace on siltstone;streaming cut to light yellow with streaming amber visible cut; brown residue fluoresces dull yellow-orange. Sand/Sandstone (8370-8495) = light gray to medium light gray to medium gray with greenish to medium bluish gray hues; upper very fine to lower fine grain;well sorted;sub-angular to sub-rounded;moderate to low sphericity;some exhibit a frost or grind abrasion;dominated by loose sands;clayey/silty matrix;firm to friable to moderately hard;predominantly translucent to milky white to very light gray quartz;trace amounts of orange lithics;pale green to light green glauconite content is increasing with depth and becoming very abundant;trace amounts of pyrite; trace amounts black to dark brown lithics; obm odor; even dull yellowish white sample fluorescence; faint dull yellow to slow milky white cut fluorescence; slow streaming amber to dark amber visible cut; light to medium straw visible residue; dull yellow residual fluorescence. Sand/Sandstone(8495-8580)=light gray to medium light gray to medium gray with brownish and greenish gray; upper very fine to lower fine grain; moderate to well sorted; sub-angular to sub-rounded; moderate to low sphericity;predominate loose quartz grains and glauconite fragments in a clayey/silty matrix;firm to friable to moderately hard;predominantly translucent to milky white to very light gray quartz;pale green to light green glauconite;trace amounts of pyrite and orange lithic fragments;even dull yellowish white sample fluorescence; faint dull slow milky white cut fluorescence; slow streaming amber visible cut; light straw visible residue fluoresces dull yellow. 23 CAFIRIG eni 0111-01 and PB1 Sandstone (8590-8730) = medium to medium light gray with slight greenish secondary hue; lower fine to upper very fine to upper fine grained; well to moderately well sorted; sub-rounded to sub-angular with moderate sphericity to sub-spheroidal;disaggregated loose sands to friable sandstone cuttings;predominantly translucent milky white to light gray to clear colorless quartz; common to abundant pale blue green to moderate blue green glauconite;30-40%dark brown to black lithics gives slight salt and pepper appearance; trace orange and yellow lithic fragments; occasional light brownish gray to pale yellowish brown silty cuttings scattered through-out sample interval slightly increasing with depth; strong obm odor;trace amount of light brown oil staining; 100% even dull yellow sample fluorescence; fast streaming milky yellowish white cut fluorescence;streaming amber to light brown visible cut; light amber visible residue;dull yellow white residual fluorescence; moderately calcareous. Sandstone(8730-8850) = medium light to light gray to olive gray throughout sample interval; lower fine to upper very fine to trace lower medium grained;grain size slightly increasing with depth of interval;moderately well to well sorted; sub-rounded to sub-angular; moderate to high sphericity; mainly disaggregated loose sands; friable in part; common to abundant light green to moderate blue green to dusky blue green fine grained glauconite;abundant brownish black to black very fine grained lithics;trace orange and yellow jasper; trace orangish pink to tan shell fragments; moderately to slightly calcareous; obm odor; general obm bright white fluorescence; 100% even dull yellow sample fluorescence; slow streaming yellowish white cut fluorescence; slow streaming light straw to straw visible cut; faint straw visible residue; faint dull yellow residual fluorescence. Sandstone(8850-8970) = medium light to medium gray to light brownish gray throughout sample interval; upper very fine to lower fine to upper fine grain;well to very well sorted;sub-rounded to sub-angular;moderate to sub- spheroidal; disaggregated loose sands; friable to firm; sandstone cuttings seem to be grained supported graded with a more silty matrix supported in the very fine grained cuttings; predominantly translucent milky white to slightly smokey quartz to light gray;about 40%dark brown to black very fine grained lithics; common to abundant pale blue green to dusky blue green glauconite; strong obm odor; bright white obm fluorescence; 100% even dull yellow with 20% patchy golden oil fluorescence in sandstone cuttings; blooming milky yellow white cut fluorescence;fast streaming dark amber visible cut; medium amber residue fluoresces dull yellow. Sandstone/Silty Sandstone (8970-9060) = light to medium light gray to secondary brownish hue overall; upper very fine to lower fine to trace upper fine in part;well sorted; sub-rounded to sub-angular; moderate to high sphericity;disaggregated;silty sandstones are firm to friable;silty cuttings are dense to brittle;silty gritty texture grading between silty sandstone to sandstone;grades to light brown to brownish gray siltstone at base of interval;confirmation of fault crossing at 9060';trace orange jasper;trace to common moderate blue green to dusky blue green glauconite;obm odor;trace light brown oil stain visible in top of interval losing it at base of interval;80%even dull yellow sample fluorescence with 10-20%patchy golden yellow in sandstone cuttings; dull yellowish white cut fluorescence; amber to dark amber visible cut; light amber to dark straw residue fluoresces dull golden yellow; moderately calcareous. FAULT#2 11-01 (REP) 9061.0 MD/-3675.1 TVDSS BASE OA SAND 9190.0 MD/-3664.0 TVDSS Siltstone(9090-9210)=light gray to medium light gray to medium gray;overall dense ranging from brittle to tough to crumbly; irregular fracture; round nodule shape cuttings habit slightly elongated; dull earthy luster; generally gritty to silty texture;trace upper very fine to lower fine sandy siltstone cuttings;trace pyrite found as individual grains;trace pale yellowish orange to tan shell fragments;trace amounts of very fine grained coal fines and thin carbonaceous micro-lamina on siltstone cuttings; strong obm odor; no oil staining visible in siltstone samples;obm fluorescence contaminates most of sample but 10-20%golden yellow oil fluorescence is visible; slow light straw cut fluoresces to faint yellow; trace to faint light straw visible residue; dull yellow residual fluorescence; non calcareous. ®�! 24 CAN YRIG eni 0111-01 and PB1 OA SBL-4 9257.0 MD/-3657.4 TVDSS Siltstone(9210-9300)=medium light to medium gray to light brownish gray overall;dense tough to crumbly tenacity; irregular fracture; nodular to slightly irregular cuttings habit; dull earthy to somewhat greasy luster; silty gritty to granular with depth; sample interval grades from very silty to more sandy at base; grading from sandy silt-stone to silty sandstone; trace to common brilliant green to dusky blue green glauconite towards base of interval;trace to no visible oil stain; 10-20% patchy golden yellow oil fluorescence in sandy cuttings; faint yellow white cut fluorescence; dark straw visible cut; faint light straw residue fluoresces dull yellow. Sandstone(9300-9420)=medium light to medium gray to olive gray throughout sample interval;lower fine to upper very fine to trace upper fine grained;well to very well sorted;sub-rounded to sub-angular;moderate to high sphericity;disaggregated loose sands to friable slightly firm sandstone cuttings;translucent milky white to transparent to slightly smokey quartz predominates; abundant pale green to dusky blue green fine grained glauconite gives sample the olive gray hue; trace to common orangish pink to pale yellowish orange shell fragments; obm odor; trace light brown oil staining; 100%even dull yellow sample fluorescence; streaming milky yellowish white cut fluorescence; slow streaming amber visible cut; faint light amber visible residue fluoresces dull yellow. OA SBL-3 9447.0 MD/-3643.3 TVDSS Sandstone(9420-9540)=medium light to light gray with secondary brownish hue throughout sample interval; lower fine to upper very fine grained;well sorted; sub-rounded to sub-angular; moderate to highly spherical; disaggregated loose sand; grading from sandstone to silty sandstone with depth; grading to a light brown to brownish gray siltstone;trace to common pale green to moderate green fine grained glauconite;trace pyrite grains and orange jasper;strong obm odor; 10-20%light brown oil staining in sandstone cuttings; 10-20%over obm contamination is golden yellow oil fluorescence found in sandstone cuttings; slow light amber cut fluoresces faint yellowish white;faint straw visible residue fluoresces faint yellow;slightly calcareous possibly caused by safe-carb additive. Siltstone/Sandy Siltstone(9540-9690)=medium light gray to medium gray to light brownish gray throughout sample interval;dense tough to crumbly to slightly brittle;irregular fracture;upper and lower very fine grained; nodular slightly elongated cuttings habit;earthy dull luster to slightly waxy;clayey silty texture to silty gritty with included sands; locally slightly granular with increased sands; trace to common dark brown to black fine grained lithic fragments; dark brown/black coal fines and thin micro- lamina visible within siltstone cuttings; trace pyrite and orange jasper scattered within samples; trace tan to orangish pink shell fragments; non calcareous except for very calcareous shell fragments; strong obm odor; no visible oil stains; general obm fluorescence; <5%golden yellow oil fluorescence;slow streaming light straw visible cut;slow streaming faint yellow cut fluorescence; faint straw visible residue; faint yellow residual fluorescence. OA SBL-2 9695.0 MD/-3640.2 TVDSS Sandstone/Silty Sandstone(9690-9780)=light gray to light bluish gray to medium light gray with occasional light brownish gray hues;predominately quartz framework with occasional grayish black lithics and glauconite; upper very fine to lower fine grains; well to very well sorted; sub-angular to sub-rounded; moderate to high sphericity;hardness ranging from easily friable to moderate hard;ranges from grain supported to a silty matrix; no apparent bedding; predominately loose unconsolidated light brownish gray to medium light gray and translucent quartz grains; occasional bleeding of oil from larger fragments of sandstone;strong odor of obm; general obm fluorescence; faint yellow cut; faint orange residual cut. Sandstone(9790-9895)=medium to medium light gray with light greenish and brown secondary hues;upper very fine to lower fine to upper fine grained;well to moderately well sorted; sub-angular to sub-rounded with moderate sphericity to sub-spheroidal;disaggregated loose sands to friable sandstone cuttings;predominantly translucent milky white to light gray to clear colorless quartz;trace amounts of pale blue green to moderate blue green glauconite;trace amounts of orange lithics;common to trace amounts of dark gray to dark brown to black lithics give salt and pepper appearance; strong obm odor;trace to common amounts of light brown oil staining; typical obm fluorescence; yellowish brown visible cut; orangish brown residual cut. 25 CANRIG Oft eni 0111-01 and PB1 Sandstone(9895-10020)=very light gray to light gray to medium gray to light bluish gray with occasional light brownish gray;predominately quartz framework with occasional dark lithics;lower fine to upper very fine;very well to well sorted;sub-rounded to sub-angular to angular;moderate to high sphericity;easily friable to friable; predominately loose disaggregated quartz grains; moderate reddish orange to orange jasper content ranges from 5%-15%with amounts generally increasing with depth; trace to common amounts of grayish black to brownish black to black lithics give a salt and pepper appearance with the very light gray quartz grains;trace amounts of biotite present;common amounts of glauconite throughout interval;strong obm odor;typical obm fluorescence with some faint orange fluorescence on sandstone; faint yellowish orange visible cut; slight yellow-orange residual cut. Sandstone(9895-10045)=very light gray to light gray to medium gray to light bluish gray;quartz framework with occasional dark gray to black lithics; upper very fine to lower fine with occasional upper fine;very well to well sorted; sub-rounded to sub-angular to angular; moderate to high sphericity; easily friable to firm; predominately loose disaggregated light gray to medium gray quartz grains and occasional very fine to fine grains of glauconite; trace to common amounts of siltstone ranging from easily friable to mod-hard; trace amounts of jasper present;trace to common amounts of grayish black to brownish black to black lithics give a salt and pepper appearance with the very light gray quartz grains;trace to common amounts of orangish pink shell fragments increasing amounts with depth;strong obm odor;typical visible obm fluorescence;slight faint orange cut; faint white residual cut. Sand/Sandstone(10045-10200) = light gray to medium gray with olive gray sub-tones; upper very fine to lower fine grain; sub-rounded to sub-angular; very well sorted to well sorted; primarily dis-aggregated unconsolidated sand; grain supported; quartz with glauconite, shell and dark lithic fragments; dull green fluorescence from obm; bluish white cut; faint white residual cut. Sand (10200-10280)=medium to medium dark gray with an overall moderate salt and pepper appearance; upper very fine to fine grain; quartz framework; very well to well sorted; sub-round to sub-angular with occasional angular;moderate sphericity;dominantly disaggregated unconsolidated light to medium translucent gray, light greenish gray quartz with traces of glauconite, black lithic grains and shell fragments; trace grain supported fragments;easily friable to friable;typical obm odor and fluorescence;milky white fluorescence cut; yellowish white residual ring. Sand(10280-10345)=medium to medium light gray with light greenish gray secondary hues; upper very fine to lower fine with occasional upper fine grain;sub-rounded to sub-angular;very well to well sorted; moderate sphericity;quartz framework;trace to abundant amounts of glauconite;trace to fair amounts of shell fragments and dark lithic grains; dull yellow fluorescence from obm; odor from obm; milky white fluorescence cut; yellowish white residual ring. Sand(10345-10405)=medium light gray to light bluish gray to medium gray;dominantly disaggregated upper very fine to lower fine quartz with very fine to fine grains of glauconite; no evident bedding; trace amounts of orangish pink shell fragments;trace amounts of free oil;no odor above background levels;typical visible obm fluorescence; milky yellow cut fluorescence; weak light brown to faint yellow residual cut. Sand/Sandstone(10405-10535)=medium gray to medium light gray with light bluish and light brownish gray hues; disaggregated sand with trace to common friable to firmly friable sandstone fragments; quartz framework; upper very fine to lower fine grain quartz;well to very well sorted; sub-angular to sub-rounded to angular;moderate sphericity;mostly grain supported to sandstone with some having a slight silty matrix; light gray and medium light gray grains predominate;common to abundant amounts of greenish gray to pale green glauconite; trace amounts of pinkish orange shell fragments; trace to common amounts of small dark gray, brownish black and black lithics ranging from very fine to fine grain;trace amounts of light orange jasper;90% of visible sample fluorescence is milky white to yellow while 10% is a light orange; bright light blue fluorescence cut; no odor above obm;trace amounts of free oil; light brown residual cut. Sand(10535-10594)=light gray to medium light gray;disaggregated sand;upper very fine to lower fine grain; moderate to very well sorted;moderate to low sphericity;trace amounts of siltstone;glauconite and dark lithics common; typical visible obm fluorescence with some faint orange; bright blue cut; light brown residual cut. ww� 26 CA I G eni 0111-01 and PB1 3.4 Connection Gas Summary 1 Unit=0.05% Methane Equivalent Depth (ft) Background Units C-1 C-2 C-3 C-4 C-5 Gas Above MD TVDSS (Units) Background (ppm) (ppm) (ppm) (ppm) (ppm) 5902 -3580 650 200 96167 1550 1485 2334 1302 6027 -3608 224 124 28188 319 249 390 208 6189 -3615 133 65 28744 233 109 121 62 6569 -3607 40 48 26084 201 98 123 49 3.5 Trip/Wiper Gas Summary 1 Unit=0.05% Methane Equivalent Depth at Trip(ft) Trip To Depth (ft) Max Gas Pumps Off Comments MD TVDSS MD TVDSS (units) (hours) 2334 -2107.2 Surf - 253 - Run 13-3/8" Casing ; Swab gas 2334 -2107.2 Surf - 14 - Run 13-3/8" Casing 4711 -3163.2 Surf - 86 21.0 Trip for NB 3 5016 -3271.9 Surf - 8 17.8 Trip for mud motor 10594 -3634.4 Surf - 67 15 Run clean out run ; Wiper gas 27 CANRIG 1.1 1 eni 0111-01 and PB1 3.6 Sampling Program And Sample Dispatch Sample Program Dry samples: (2 sets) Every 30'from 1000'to TD (10,594' MD). No Wet Samples Sample Dispatch Set Processed As Frequency* Interval* Dispatched to Washed, dried, stored Fugro Data Solutions In envelopes. A Reference Samples. 30' 1000'to 6007' 3311 S. US Hwy 77 Set Owner: ENI Schulenburg, TX 78956 Washed, dried, stored AOGCC B In envelopes. 30' 1000'to 6007' 333 W. 7TH Ave., Suite 100 Reference Samples. Anchorage, AK 99501 Set Owner: State of Alaska Washed, spin dried, stored Fugro Data Solutions In sample vials. C Reference Samples. 30' 6007'to 10594' 3311 S. US Hwy 77 Set Owner: ENI Schulenburg, TX 78956 Washed, spin dried, stored AOGCC D In sample vials. 30' 6007'to 10594' 333 W. 7TH Ave., Suite 100 Reference Samples. Anchorage, AK 99501 Set Owner: State of Alaska Sample frequency and interval may be altered locally according to on-site geologist. 28 CANRIG Mi 0111-01 and PB1 4 PRESSURE AND FORMATION STRENGTH DATA 4.1 Pore Pressure Gradient Evaluation Formation Primary Secondary Top Of Interval Pore Pressure Trend Indicators Litholoqy(%) Lithology(%) Lf_ti (EMW, ppq) MD TVDSS Min Max Trend Permafrost Sd/Cgl 60% Sltst/Clyst 40% 8.8 9.3 Up BG,CG, MW Ugnu Sd/Cgl 60% Clyst/Sltst/Sh 2195 -1988.2 9.0 9.5 Up BG,CG,TG, MW 40/0 Schrader Bluff Sd/Sltst 80% Sltst 20% 7314 -3496 8.7 9.4 Even BG, CG, TG, MW 4.2 Quantitative Methods The primary indicators used for PPG evaluation were gas trends relative to mud weight(MW)and effective circulating density(ECD), including increases in background gas(BG),appearance and trends of connection gas(CG), lost circulation(LC),and magnitudes of trip gas(TG)and wiper gas(WG). Regional pore pressure trends from sonic data,provided by client,and surface manifestations of hole conditions were also considered. As a reference, PPG is calculated initially with a formula provided by Canrig, and then modified using the indicators described above, and DXC and resistivity (RES) data. The formula uses DX, ECD, and BG as measured by total ditch gas: PPG = ECD—(0.6-((.001*TLGSU)+(0.05"DX))) The formula has certain limitations,such that it does not allow for a PPG more than 1 ppg less than the ECD, and TLGSU must be differentiated from show gas and gas carried from over pressure zones, and is dependent on reliable DX data. However,the formula proved useful in helping establish a PPG range,when establishing trends, as with DXC data,with data points in shale intervals. 29 CAIIIG eni 0111-01 and PB1 5 DRILLING DATA 5.1 Daily Activity Summary 09/20/2010 Rig up, prep for rig move; reconfigure standpipe for ECD unit;jack and move utility module; move mats, cut herculite;spot sub over well; move rig over 0111-01; hook up interconnects between two modules; berm rig; install riser and flow line; set drilling adapter, riser and test to 500 psi. 09/21/2010 Finish rigging up rig; pick up drill pipe, install mouse hole; pick up drill pipe and rack back; pick up heavy wall drill pipe; rack back; calibrate Canrig and SLB blocks. 09/22/2010 Pick up/make up conductor,clean out BHA; rotary drill from 122'to 160'and clean out conductor;pick up BHA and orientate gyro data tool. Spud well and rotary drill from 160'to 342';trip out of hole from 342'to 158';pick up remaining BHA; rotary drill from 342'to 777'. 09/23/2010 Rotary drill from 777'to 1500',wob=20k, gpm=600, ecd=9.68; rotary drill from 1500'to 1915',wob-20k, gpm =610, ecd = 9.55; rotary drill from 1915'to 2311',wob 20k, gpm =750, ecd = 9.91. 09/24/2010 Rotary drill from 2311'to 2347'(td),wob 20,gpm 650,ecd 9.78;circulate and condition(cbu);back ream from 2348'to 684'; circulate and condition hole until clean;trip in hole from 684'to 2347'; circulate and condition, pump sweep; trip out of hole from 2347'to 216'; lay down BHA; rig up to run casing; run casing to 590'. 09/25/2010 Run casing from 590'to 2334';circulate and condition mud; pump cement;run casing floats, rig down casing equipment; nipple down diverter system, drilling head adapter; nipple up bop stack, clean pits. 09/26/2010 Nipple up and test BOPs;pick up BHA#3; run in hole to 1038',make up ghost reamer;shallow test mwd tools; trip in hole;tag cement @ 2241'; circulate and condition mud; pressure test casing to 2500 psi; drill cement from 2241'to 2329'; tag shoe @ 2331'; drill shoe; drill cement. 09/27/2010 Rotary drill 20'new hole from 2347'to 2367';displace spud mud to LSND(8.8+mw);perform leak off test;test results 12.1 EMW; rotary drill from 2367'to 3719'. 09/28/2010 Rotary drill from 3719'to 4711'; trip out of hole due to poor rop to 3380'at midnight. 09/29/2010 Trip out of hole from 3410'to 650'; R and R BHA;trip in hole to 2243';cut and slip drill line,service blocks;trip in hole from 2243'to 4580';wash and ream from 4580'to 4708', hole under gauge. 09/30/2010 Wash and ream from 4708'to 4711'; rotary drilling from 4711'to 5016';encountered pressure loss,from 3600 psi to 2300 psi, test surface equipment, surface equipment okay, therefore down hole problems; pull out of hole on elevators from 5019'to 650'; lay down ghost reamer, lay down heavy weight, lay down BHA; clean floor, service top drive; pick up BHA; trip in hole, shallow test tools. 30 CANRIG rni 0111-01 and PB1 10/01/2010 Pick up remaining BHA; trip in hole; drill from 5016'to 5936'. 10/02/2010 Rotary drill from 5936'to 6007'; circulate bottoms up eight times; trip out of hole; change rams; test bops; rig up to run casing 9 5/8"casing; run 9 5/8"casing. 10/03/2010 Continue running in hole with 9 5/8"casing. Run casing to TD at 5991'md. Circulate 2 bottoms up then pump cement. Set and test pack off. Change and test rams. Clean pits and prep to pick up 5"drill pipe as of midnight. 10/4/2010 Continue picking 5"drill pipe and rack back stands. Pick up BHA#6. Run in hole and shallow test tools. Trip in hole to 2300'and log cement bonding. Run casing pressure test. Circulate bottoms up and displace mud and prepare to drill out cement as of midnight. 10/5/2010 Continue displacing oil based mud. Drill out of 9 5/8"shoe at 6007'and drill 20ft of new hole to 6027'. Circulate bottoms up. Reciprocate pipe. Perform successful LOT to EMW of 12.84ppg. Drill ahead from 6027'to 6977'md. Trip back to 6416'and begin trough for open hole sidetrack as of midnight. 10/6/2010 Started building trough for open hole sidetrack from 6378'to 6403'. Serviced top drive due mechanical failure and not rotating. Racked back one stand and to trough at 6327'to 6357'. Drill ahead from kick off point of 6357'to current depth as of midnight. 10/7/2010 Continued drilling ahead from 7118'to current depth of 9310'md with no issues.Max gas for the day was 541 u at 8696'md. 10/8/2010 Continue drilling ahead from 9310'to TD at 10594'md with no issues. Circulate 4+ bottoms up and condition hole reciprocating pipe. Back ream out of hole from 10118'to 5918'. Circulate bottoms up inside casing. Pull out of hole on elevators. 10/9/2010 Circulate 3 bottoms up inside shoe. Continue tripping out of hole from 5910'to 477'. Lay down BHA. Service top drive and perform BOP test. Pick up BHA and begin tripping in hole. 10/10/2010 Trip in hole from 2718'to 5942'. Cut and slip drill line. Trip in hole from 5942'to 10594'. Tight spots at 6978'-6996', 7570'-7819', 8683'-8815', 9468'-9485', and 9677'-10155'. Circulate 1.5 bottoms up and pump sweep. Pull out of hole from 10594'to 10347'. Back ream out of hole from 10347'to 9000'. Circulate 3 bottoms up. Pull out of hole to 8241'as of midnight with tight spot at 8625'. 10/11/2010 Continue back reaming from 8241'. Pull out of hole on elevators from 8241'to shoe with a tight spot at 6447'. Run in hole on elevators. Circulate 7 bottoms up. Pull out of hole on elevators and lay down BHA. 10/12/2010 Run in hole with 5 1/2" liner. Tag bottom at 10599'and set liner at 10594'. Circulate 4 bottoms up and drop ball. Test packer for 10 minutes. Pull out of hole and lay down 90 joints of drill pipe. 31 CANRI] V eni 0111-01 and PB1 10/13/2010 Continue laying down drill pipe. Lay down liner running tool. Run in hole to 5769'and displace to 9.0 ppg brine. Clean pits and shakers. Circulate and condition well out of balance. Lay down remaining drill pipe and run wire line logs. 10/14/2010 Continued to run cased hole wire line logs. Lay down logging tools and pull wear ring. Rig up to run tubing. Pick up completion assembly and run in hole with 3 1/2"tubing to 2337' as of midnight. 10/15/2010 Continuing to run 3 1/2"completion tubing.At a current depth of 7134'as of midnight. 10/16/2010 Run 4 1/2"completion tubing. Test fiber optics. Land tubing hanger. Test well head and set packer. Test completion tubing to 4000 psi for 30 minutes. Nipple down BOP's. 32 CANRIG I" eni. 0111-01 and PB1 5.2 Survey Data Measured Inclination Azimuth True Vertical Latitude Departure Dogleg Depth Vertical Section (ft) (ft) Rate (ft) (deg) (deg) Depth (ft) (ft) N(+),S(-) E(+),W(-) (°/100ft) 0 0 0 0 0 0 0 0 108.31 0.15 219.54 108.31 -0.05 -0.11 -0.09 0.14 202.93 0.30 82.56 202.93 -0.19 -0.18 0.07 0.45 294.57 0.27 142.79 294.57 -0.50 -0.32 0.44 0.31 312.97 0.21 62.88 312.97 -0.55 -0.34 0.5 1.69 392.65 0.53 30.98 392.65 -0.39 0.05 0.82 0.47 453.92 0.20 44.52 453.91 -0.23 0.37 1.04 0.55 545.14 1.49 344.40 545.13 0.96 1.63 0.84 1.53 586.95 2.63 347.40 586.91 2.39 3.09 0.48 2.75 636.99 4.01 345.49 636.86 5.16 5.91 -0.21 2.77 676.90 4.81 347.24 676.65 8.08 8.89 -0.93 2.03 731.83 6.55 346.96 731.31 13.24 14.19 -2.14 3.16 827.90 8.21 340.17 826.58 25.17 25.98 -5.71 1.94 923.33 11.69 334.64 920.57 41.46 41.13 -12.16 3.78 1020.63 13.88 335.17 1015.45 62.86 60.62 -21.28 2.25 1115.38 18.08 333.97 1106.52 88.80 84.16 -32.51 4.45 1210.26 22.46 338.86 1195.51 121.32 114.31 -45.51 4.95 1306.76 26.03 338.72 1283.48 160.34 151.24 -59.85 3.70 1369.31 28.38 343.30 1339.11 188.25 178.28 -69.11 5.03 1463.17 29.21 344.96 1421.37 231.83 221.76 -81.46 1.23 1558.45 26.45 345.01 1505.62 274.53 264.72 -92.99 2.90 1654.58 25.76 343.83 1591.94 315.24 305.47 -104.34 0.90 1749.61 26.77 343.48 1677.16 355.88 345.82 -116.18 1.08 1846.40 27.06 341.23 1763.47 398.45 387.56 -129.46 1.09 1941.91 31.47 340.23 1846.77 444.11 431.62 -144.89 4.65 2038.43 33.97 339.84 1927.97 495.27 480.65 -162.71 2.60 2133.58 35.80 340.86 2006.02 548.56 531.90 -181.00 2.02 2229.82 40.33 339.79 2081.77 606.68 587.74 -201.00 4.76 2267.28 41.36 341.44 2110.11 630.65 610.85 -209.12 3.98 2402.52 42.58 343.68 2210.66 718.45 697.13 -236.21 1.43 2500.50 45.01 343.59 2281.38 783.97 762.19 -255.31 2.48 2594.24 48.66 342.83 2345.50 850.16 827.63 -275.07 3.94 2690.12 51.62 341.49 2406.94 921.74 897.67 -297.63 3.27 2785.70 54.57 342.01 2464.33 996.19 970.25 -321.56 3.12 2882.97 58.76 341.7 2517.77 1075.31 1047.46 -346.87 4.32 2977.90 62.25 342.15 2564.50 1155.74 1126.00 -372.49 3.70 3073.09 64.33 342.21 2607.29 1238.43 1206.94 -398.51 2.19 3169.16 65.81 343.35 2647.78 1322.94 1290.16 -424.30 1.88 3264.68 66.40 343.54 2686.47 1407.40 1373.87 -449.18 0.64 3359.24 67.31 342.62 2723.64 1491.64 1457.05 -474.49 1.31 3454.82 67.89 341.63 2760.06 1577.60 1541.15 -501.61 1.13 Surveys(continued) 33 CAM IG IA cni. 0111-01 and PB1 Measured Inclination Azimuth True Vertical Latitude Departure Dogleg Depth Vertical Section (ft) (ft) Rate (ft) (deg) (deg) Depth (ft) (ft) N(+), S(-) E(+),W(-) (/100ft) 3454.82 67.89 341.63 2760.06 1577.6 1541.15 -501.61 1.13 3552.31 68.2 340.13 2796.51 1665.99 1626.58 -531.23 1.46 3646.95 68.35 340.07 2831.55 1752.18 1709.25 -561.16 0.17 3742.22 68.54 340.14 2866.55 1839.04 1792.57 -591.31 0.21 3839.61 68.70 339.73 2902.05 1928.00 1877.75 -622.42 0.43 3935.36 68.51 340.03 2936.98 2015.46 1961.46 -653.09 0.35 4031.65 68.64 340.24 2972.15 2103.33 2045.76 -683.55 0.24 4127.71 68.63 340.42 3007.15 2190.96 2130.00 -713.66 0.17 4224.14 68.69 340.17 3042.24 2278.95 2214.56 -743.94 0.25 4318.54 68.45 340.30 3076.73 2365.05 2297.26 -773.66 0.28 1 4414.89 68.94 340.14 3111.74 2453.02 2381.72 -804.04 0.53 4509.22 68.91 340.10 3145.66 2539.30 2464.50 -833.97 0.05 4606.08 68.97 340.06 3180.46 2627.92 2549.48 -864.77 0.07 4700.18 70.85 340.71 3212.79 2714.47 2632.72 -894.43 2.10 4796.68 70.03 342.03 3245.09 2803.19 2718.89 -923.48 1.54 4890.65 69.19 342.73 3277.83 2888.78 2802.83 -950.14 1.13 4961.01 67.34 343.91 3303.89 2952.03 2865.44 -968.90 3.06 5061.76 67.40 342.99 3342.66 3041.96 2954.58 -995.39 0.84 5157.70 68.91 343.84 3378.36 3128.10 3039.92 -1020.81 1.78 5253.11 69.26 341.34 3412.42 3214.62 3124.95 -1047.47 2.47 5347.37 69.02 336.45 3446.00 3301.28 3207.09 -1079.17 4.85 5443.74 67.60 339.79 3481.63 3389.61 3290.17 -1112.55 3.54 5538.17 67.01 338.18 3518.06 3475.33 3371.49 -1143.79 1.69 5632.86 68.26 343.30 3554.11 3560.94 3454.12 -1172.64 5.17 5729.63 71.89 343.82 3587.08 3648.86 3541.37 -1198.38 3.79 5824.47 75.32 342.53 3613.85 3736.96 3628.44 -1224.72 3.84 5917.71 76.74 341.65 3636.36 3824.98 3714.53 -1252.55 1.78 6032.37 82.74 346.40 3656.79 3933.72 3822.93 -1283.53 6.63 6127.17 87.24 348.32 3665.06 4023.17 3915.05 -1304.19 5.16 6222.64 89.39 348.69 3667.87 4112.96 4008.56 -1323.20 2.29 6317.77 91.24 348.39 3667.35 4202.45 4101.79 -1342.10 1.97 6415.02 88.48 347.61 3667.58 4294.24 4196.91 -1362.32 2.95 6510.32 88.55 343.58 3670.06 4385.39 4289.16 -1386.01 4.23 6605.94 89.83 341.34 3671.41 4478.26 4380.32 -1414.83 2.70 6700.67 89.38 338.21 3672.06 4571.22 4469.19 -1447.57 3.34 6797.18 89.21 335.96 3673.25 4666.69 4558.07 -1485.14 2.34 6893.30 88.06 334.74 3675.54 4762.14 4645.41 -1525.22 1.74 6990.01 88.06 333.11 3678.81 4858.39 4732.22 -1567.70 1.68 7086.27 89.98 330.84 3680.46 4954.47 4817.17 -1612.92 3.09 7181.15 88.41 330.92 3681.79 5049.27 4900.05 -1659.09 1.66 7276.50 88.12 328.97 3684.68 5144.55 4982.54 -1706.82 2.07 34 CANIIIG ilni eni 011 1-01 and PB1 Surveys(continued) Measured Inclination Azimuth True Vertical Latitude Departure Dogleg Depth Vertical Section (ft) (ft) Rate (ft) (deg) (deg) Depth (ft) (ft) N(+),S(-) E(+),W(-) 0100ft) 7372.37 86.29 326.15 3689.35 5240.27 5063.34 -1758.17 3.50 7467.38 86.52 325.14 3695.31 5334.96 5141.62 -1811.68 1.09 7564.07 88.49 324.85 3699.52 5431.35 5220.74 -1867.09 2.06 7659.98 88.38 322.50 3702.14 5526.84 5297.98 -1923.88 2.45 7755.24 86.49 318.78 3706.40 5621.04 5371.54 -1984.22 4.38 7851.27 87.43 316.61 3711.50 5715.16 5442.46 -2048.76 2.46 7946.43 88.23 315.39 3715.10 5807.91 5510.86 -2114.81 1.53 8043.08 88.49 312.30 3717.87 5901.27 5577.77 -2184.48 3.21 8138.63 87.41 308.29 3721.29 5991.84 5639.52 -2257.30 4.34 8234.55 86.35 303.53 3726.51 6080.10 5695.68 -2334.85 5.08 8330.45 86.58 302.67 3732.42 6166.41 5747.95 -2415.03 0.93 8425.59 88.75 302.77 3736.30 6251.84 5799.33 -2495.00 2.28 8522.25 89.55 301.59 3737.73 6338.30 5850.80 -2576.80 1.47 8617.54 90.38 301.59 3737.79 6423.10 5900.72 -2657.97 0.87 8714.90 89.92 301.57 3737.54 6509.74 5951.70 -2740.91 0.47 8809.47 91.15 302.03 3736.65 6594.06 6001.53 -2821.28 1.39 8905.15 91.26 302.50 3734.64 6679.69 6052.60 -2902.17 0.50 9000.66 92.41 303.65 3731.58 6765.75 6104.69 -2982.16 1.70 9096.88 94.58 302.91 3725.72 6852.47 6157.39 -3062.44 2.38 9192.69 95.90 303.94 3716.97 6938.72 6209.94 -3142.07 1.74 9288.52 95.24 304.89 3707.67 7025.64 6263.85 -3220.75 1.20 9383.71 93.95 304.58 3700.04 7112.33 6317.91 -3298.73 1.39 9478.86 91.81 304.16 3695.26 7198.90 6371.55 -3377.16 2.29 9574.13 89.61 304.88 3694.08 7285.78 6425.54 -3455.64 2.43 9670.00 90.78 307.53 3693.75 7374.33 6482.16 -3532.99 3.02 9766.89 90.35 309.33 3692.80 7465.20 6542.38 -3608.89 1.91 9861.89 90.61 309.25 3692.00 7554.79 6602.53 -3682.41 0.29 9957.33 89.21 308.56 3692.15 7644.57 6662.47 -3756.68 1.64 10053.76 89.15 307.67 3693.53 7734.82 6721.98 -3832.54 0.92 10150.37 91.29 306.97 3693.16 7824.76 6780.55 -3909.36 2.33 10245.47 91.26 306.15 3691.05 7912.81 6837.18 -3985.73 0.86 10340.63 91.15 304.91 3689.04 8000.26 6892.47 -4063.15 1.31 10433.89 90.12 302.78 3688.01 8084.86 6944.40 -4140.60 2.54 10528.73 90.15 301.55 3687.79 8169.69 6994.89 -4220.88 1.30 35 CANRIG Cr) \ \ Pf ¥ \ \ cD \ � \ it 3 UWI % % 2 % 2! ± ¥ OT- 2ic∎1 (0 NI O ci ci _ # ¥ ct > O 0) co c) 0) k o N r m U) I N N k \ = E CO S \ E $ = & N U) = w '- CO ¥ a) Ot N k 0 0) = o ¥ - CO w a)— N N k CO a = a +c,— �\ k o X00 CD CD as � � nV_ fs_ C C TgCO ©�} 9 $ � T � b � % ƒ Cƒ u) \ \ r - - - 5 0 0 ra k N N Z I N G G N =kmxmx o.s a + TO _C _C 0$ I- / x kc 7S 75 kG IXI2I2U) OC ■ _ f f f @ 14 § CO 2 2 s- et = n b3 N Z Z Z Z I Z 2 CIO CO CO C° S ■ i , § § CC CO q iti N. co V T T a) Q O E a) O O O co 0 0 0 0 0 0 0 C - H () T T co O) ' co co T T T M CO p a) r T N T N LL o .0 U � J = co co O co � LO N- Q) co co CO , V +� Q. 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SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH MW VIS PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) @ @ CONNECTION GAS HIGH ETHANE(C-2) @ @ AVG PROPANE(C-3) @ @ CURRENT BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG PENTANE(C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY RIG UP,PREP FOR RIG MOVE;RECONFIGURE STANDPIPE FOR ECD UNIT;JACK AND MOVE UNITLITY MOD;MOVE MATS,CUT HERCULITE;SPOT SUB OVER WELL;MOVE RIG SUMMARY OVER OP11-01;HOOK UP INTERCONNECTS BETWEEN TWO MODULES;BERM RIG;INSTALL RISER AND FLOWLINE;SET DRILLING ADAPTER,RISER/TEST TO 500 PSI. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML$3045,RIGWATCH$1450 REPORT BY TOLLEF WINSLOW file://C:\Documents and Settings\EpochAdmin\MVIy Documents\lvly Wells\ENI\OI11-01\Daily Reports... Daily Report ENI Petroleum DAILY WELLSITE REPORT U EPOCH 01 11-01 REPORT FOR KEENER/GOERLICH DATE Sep 29,2010 DEPTH 4711' PRESENT OPERATION REAMING AND WASHING @ 4708' TIME 24:00:00 YESTERDAY 4711' 24 HOUR FOOTAGE 0' CASING INFORMATION 20"@ 160' 13 3/8"@ 2334' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 4606.08' 68.96 340.37 2628.89' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 12 1/4" HYCALOG MSX619SA2C 226208 6 x 16 2347' 4711' 2364' 28.2 6-7-BT-A-X-1-CT-ROP ROP 3 12 1/4" HUGHES MXL-1X 5172120 1 x 20,2 x 18,1 x 16 4711' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 4711'/3217' MW 8.9.1 VIS 68 PV 14 YP 28 FL 5.2 Gels 14/23/26 CL- 1100 FC 1/ SOL 4.0 SD 0.1 OIL 2/94 MBL 14 pH 9.5 Ca+ 40 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 86 CUTTING GAS @ @ WIPER GAS 0 CHROMATOGRAPHY(ppm) SURVEY 0 METHANE(C-1) @ @ CONNECTION GAS HIGH 0 ETHANE(C-2) @ @ AVG 0 PROPANE(C-3) @ @ CURRENT 0 BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG 0 PENTANE(C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION SAND/CONGLOMERATIC SAND=DARK GRAY TO GRAYISH BLACK;UPPER VERY COARSE TO LOWER MEDIUM,PREDOMINATELY UPPER TO LOWER COARSE;SPHERICAL TO SUB-DISCOIDAL;SUB-ROUNDED TO ROUNDED CHERT,ANGULAR TO SUB-ANGULAR QUARTZ;POORLY SORTED;UNCONSOLIDATED SAND,CONSOLIDATED SANDSTONE;SILICEOUS CEMENT;GRAIN SUPPORTED AND MATRIX/CEMENT SUPPORTED QUARTZ SANDSTONE;TEXTURALLY IMMATURE;COMPOSITIONALLY IMMATURE;GRAYISH BLACK TO LITHOLOGY GRAY AND BLUISH GREEN CHERT,CHERT IS BOTH ANGULAR AND ROUNDED,ANGULAR CHERT HAS CONCOIDAL FRACTURES; TRANSLUCENT AND MILKY WHITE QUARTZ;QUARTZ SAND ALSO CONTAINS DISSEMINATED AND GRAIN ENCRUSTED PYRITE, BLACK CARBONACEOUS MATERIAL AND BLACK CHERT;QUARTZ SAND EXHIBITS LIGHT,10%FAINT BROWN STAIN;VERY FAINT DARK BROWN FLUORESCENCE CUT;CLEAR CUT NO RESIDUAL CUT;NO RESIDUAL FLUORESCENCE CUT NO OIL ODOR;POROSITY AND PERMEABILITY VISUALLY POOR. PRESENT SAND 100% LITHOLOGY DAILY ACTIVITY TRIP OUT OF HOLE FROM 3410'TO 650';LAY DOWN BHA;PICK UP BHA;TRIP IN HOLE TO 2243';CUT AND SLIP DRILL LINE, SUMMARY SERVICE BLOCKS;TRIP IN HOLE FROM 2243'TO 4580';WASH AND REAM FROM 4580'TO 4708',HOLE UNDER GAUGE. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML$3045, RIGWATCH$1450 REPORT BY TOLLEF WINSLOW file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY ... Daily Report ENI Petroleum DAILY WELLSITE REPORT PI EPOCH OI 11-01 REPORT FOR KEENER/GOERLICH DATE Sep 30,2010 DEPTH 5016' PRESENT OPERATION RUN IN HOLE ON ELEVATORS TIME 24:00:00 YESTERDAY 4711' 24 HOUR FOOTAGE 305' CASING INFORMATION 20"@ 160' 13 3/8"@ 2334' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 4890.65' 69.17 343.49 3277.98' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 12 1/4" HUGHES MLX-1X 5172120 1 x 20,2 x 18,1 x 16 4711' 5016' 305' 6.49 1-1-WT-A-E-IN-NO-DTF DTF RR 3 12 1/4" HUGHES MLX-1X 5172120 1 x 20,2 x 18,1 x 16 5016' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 251.1 @ 4980 2.6 @ 4711 136.4 15.09465 FT/HR SURFACE TORQUE 14597 @ 4911 3834 @ 4755 7649.7 7419.98877 AMPS WEIGHT ON BIT 49 @ 4711 -1 © 4747 12.7 23.48762 KLBS ROTARY RPM 99 @ 5011 54 @ 4881 85.5 80.63037 RPM PUMP PRESSURE 3685 @ 5014 2777 @ 5015 3208.5 2777.04614 PSI DRILLING MUD REPORT DEPTH 5016' MW 9.0 VIS 92 PV 14 YP 12 FL 5.8 Gels 11/16/18 CL- 1200 FC 1/ SOL 4 SD 0.1 OIL 2/94 MBL 12 pH 9.4 Ca+ 60 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 19 @ 4919 0 © 4712.00000 9.8 TRIP GAS 0 CUTTING GAS 0 @ 5015 0 @ 5015.00000 0.0 WIPER GAS 0 CHROMATOGRAPHY(ppm) SURVEY 0 METHANE(C-1) 3993 © 4979 0 @ 4712.00000 1917.7 CONNECTION GAS HIGH 0 ETHANE(C-2) @ @ AVG 9.8 PROPANE(C-3) @ @ CURRENT 0 BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG 0 PENTANE(C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION SAND/SANDSTONE/CONGLOMERATIC SAND=MEDIUM TO MEDIUM LIGHT GRAY WITH A DISTANCE BROWNISH SECONDARY HUE; WELL TO LOCALLY POORLY SORTED;FRIABLE IN PART;FINE UPPER TO MEDIUM LOWER PREDOMINATE;SCATTERED TO LOCALLY ABUNDANT MEDIUM UPPER TO COARSE AND SMALL PEBBLES AND PEBBLE FRAGMENTS;ANGULAR TO SUB-ANGULAR IN THE FINER MATERIAL;COARSER MATERIAL TENDS TO BE SLIGHTLY ROUNDED TO SUB-ANGULAR;ABUNDANT ANGULAR PEBBLE LITHOLOGY FRAGMENTS;TRANSLUCENT WHITE TO GRAY ANDS CLEAR COLORLES QUARTZ PREDOMINATE;20 TO 30%MEDIUM TO LIGHT AND DARK GRAY QUARTZITE,CHERT AND LITHIC GRAINS;VERY ABUNDANT MEDIUM TO DARK BROWNISH GRAY LITHICS AND CHERT GRAINS;TRACE GLAUCONITE;TRACE ORANGE AND MOTTLED ORANGE AND BROWN JASPER;TRACE RE-WELDED FAULT GANGE; ABUNDANT PYRITE;TRACE HARD ANGULAR SANDSTONE FLAKES;MODERATELY CALCAREOUS;TRACE MEDIUM BROWN DEAD OIL STAIN;VERY SLIGHT CALCAREOUS. PRESENT SAND 100% LITHOLOGY DAILY WASH AND REAM FROM 4708'TO 4711';ROTARY DRILLING FROM 4711'TO 5016;ENCOUNTERED PREASURE LOSS,3600 PSI TO ACTIVITY 2300 PSI,TEST SURFACE EQUIPMENT,SURFACE EQUIPMENT OKAY,THEREFORE DOWN HOLE PROBLEMS;PULL OUT OF HOLE SUMMARY ON ELEVATORS FROM 5019'TO 650';LAY DOWN GHOST REAMER,LAY DOWN HEAVY WEIGHT,LAY DOWN BHA;CLEAN FLOOR, SERVICE TOP DRIVE;PICK UP BHA;TRIP IN HOLE,SHALLOW TEST TOOLS. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML$3045. RIGWATCH$1450 REPORT BY TOLLEF WINSLOW file://C:\Documents and Settings\EpochAdmin\MVly Documents\MVly Wells\ENI\OIl 1-0... Daily Report ENI Petroleum DAILY WELLSITE REPORT I EPOCH 01 11-01 REPORT FOR GOERLICH/LONGO DATE Oct 01,2010 DEPTH 5936' PRESENT OPERATION DRILLING TO TD TIME 24:00:00 YESTERDAY 5016' 24 HOUR FOOTAGE 920' CASING INFORMATION 20"@ 160' 13 3/8"@ 2334' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 5923.38' 76.79 341.65 3638.61' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED RR 4 12 1/4" HUGHES MLX-1 X 5172120 1 x 20,2 x 18,1 x 16 5016' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 717.8 @ 5051 16.4 @ 5434 145.6 20.62574 FT/HR SURFACE TORQUE 11799 @ 5210 2 @ 5081 4415.4 26.86777 AMPS WEIGHT ON BIT 55 @ 5103 -27 @ 5046 22.8 42.13520 KLBS ROTARY RPM 83 @ 5212 0 @ 5873 37.0 0.01555 RPM PUMP PRESSURE 2714 @ 5192 41 @ 5075 2369.3 2610.06445 PSI DRILLING MUD REPORT DEPTH 5828 MW 9.1 VIS 54 PV 14 YP 26 FL 5.3 Gels 12/23/27 CL- 1300 FC 1/ SOL 5 SD 0.1 OIL 3/93 MBL 13 pH 9.6 Ca+ 40 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 659 @ 5903 0 @ 5077 70.2 TRIP GAS 0 CUTTING GAS 0 @ 5936 0 @ 5936 0.0 WIPER GAS 0 CHROMATOGRAPHY(ppm) SURVEY 0 METHANE(C-1) 104204 @ 5904 53 @ 5077 12243.3 CONNECTION GAS HIGH 195 ETHANE(C-2) 1747 @ 5886 0 @ 5268 153.7 AVG 70 PROPANE(C-3) 1651 @ 5903 0 @ 5349 79.1 CURRENT 47 BUTANE(C-4) 2610 @ 5903 0 @ 5349 123.1 CURRENT BACKGROUND/AVG 150 PENTANE(C-5) 1497 @ 5903 0 @ 5349 84.8 HYDROCARBON N SAND AND OA SAND SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION N SAND 5400- N SAND AND OA N N SAND=SAND/CONGLOMERITIC SAND=MEDIUM DARK GRAY TO MEDIUM GRAY WITH 5710 OA SAND SAND SAND GRAYISH BLACK TO BLACK SPECKLES;LOWER MEDIUM TO LOWER COARSE GRAINS WITH 5885-6013 375 OCCASIONAL UPPER VERY COARSE GRAINS;SUB-PRISMOIDAL TO SUB-DISCOIDAL SPHERICITY; OA ANGULAR TO SUB-ANGULAR;MODERATELY TO POORLY SORTED;UNCONSOLIDATED SAND; SAND GRAIN SUPPORTED;TEXTURALLY IMMATURE;COMPOSITIONALLY IMMATURE;TRANSLUCENT 659 AND MILKY WHITE QUARTZ;GREY AND BLACK CHERT,LIGHT GREEN GLAUCONITE,GREEN LITHICS,PALE YELLOWISH ORANGE SHELL FRAGMENTS,BLACK TO BROWNISH BLACK CARBONACEOUS MATERIAL WITH LAMINATIONS AND DISSEMINATED PYRITE;SLIGHT OIL ODOR; TRACE STAIN LIGHT BROWN STAIN 5%;SAMPLE FLUORESCES 50%PATCHY BRIGHT,STRAW YELLOW;CLEAR TO LIGHT BROWN CUT;NO RESIDUAL CUT;BRIGHT BLUISH WHITE RESIDUAL CUT;LIGHT BROWN TO DARK BROWN FREE OIL COLLECTING AT THE END OF THE SHAKERS; FREE OIL IN CLAYS WITH IN SAMPLE;POROSITY AND PERMEABILITY VISUALLY GOOD.OA SAND =SAND=OLIVE GRAY TO LIGHT OLIVE GRAY;UPPER FINE TO LOWER FINE,OCCASIONAL LOWER MEDIUM;SUB-PRISMOIDAL TO SUB-DISCOIDAL;ANGULAR TO SUB-ANGULAR; MODERATELY TO MODERATELY WELL SORTED;UNCONSOLIDATED SAND;GRAIN SUPPORTED; TRANSLUCENT QUARTZ;LIGHT GREEN LITHICS,DISSEMINATED PYRITE AND PALE YELLOWISH ORANGE SHELL FRAGMENTS;STRONG OIL ODOR;50%GRAINS DARK BROWN STAIN;75% SAMPLE FLUORESCES BRIGHT YELLOW GOLD;IMMEDIATE BLOOMING BRIGHT WHITE FLUORESCENT CUT;LIGHT AMBER CUT;LIGHT BROWN RESIDUAL CUT;BRIGHT WHITE RESIDUAL FLUORESCENCE;FREE OIL ON SHAKERS AND IN POSSUM BELLY. SAND=OLIVE GRAY TO LIGHT OLIVE GRAY;UPPER FINE TO LOWER FINE,OCCASIONAL LOWER MEDIUM;SUB-PRISMOIDAL TO LITHOLOGV SUB-DISCOIDAL;ANGULAR TO SUB-ANGULAR;MODERATELY TO MODERATELY WELL SORTED;UNCONSOLIDATED SAND;GRAIN SUPPORTED;TRANSLUCENT QUARTZ;LIGHT GREEN LITHICS,DISSEMINATED PYRITE AND PALE YELLOWISH ORANGE SHELL FRAGMENTS;STRONG OIL ODOR;50%GRAINS DARK BROWN STAIN;75%SAMPLE FLUORESCES BRIGHT YELLOW GOLD; file://C:\Documents and Settings\EpochAdmin\MVly Documents\My Wells\ENI\OI11-0... Daily Report IMMEDIATE BLOOMING BRIGHT WHITE FLUORESCENT CUT;LIGHT AMBER CUT;LIGHT BROWN RESIDUAL CUT;BRIGHT WHITE RESIDUAL FLUORESCENCE;FREE OIL ON SHAKERS AND IN POSSUM BELLY. PRESENT SAND 100% LITHOLOGY DAILY ACTIVITY SUMMARY PICK UP BHA;TRIP IN HOLE;DRILL FROM 5016'TO 5936'. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML$3045, RIGWATCH$1450 REPORT BY TOLLEF WINSLOW file://C:\Documents and Settings\EpochAdmin\My Documents\My Wells\ENI\OI11-0... Daily Report ENI Petroleum DAILY WELLSITE REPORT El EPOCH 0111-01 REPORT FOR GOERLICH/LONGO DATE Oct 02,2010 DEPTH 6007' PRESENT OPERATION RUNNING 9 5/8"CASING TIME 24:00:00 YESTERDAY 5937' 24 HOUR FOOTAGE 70' CASING INFORMATION 20"@ 160' 13 3/8"@ 2334' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 5923.86' 76.79 341.65 3638.61' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED RR4 12 1/4" HUGHES MLX-1X 5172120 1 x 20,2 x 18,1 x 16 5016' 6007' 991' 10.5 2-2-WT-A-E-2-NO-TD TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 417 @ 6005 16.7 @ 5937 150.0 133.26746 FT/HR SURFACE TORQUE 33 @ 6017 24 @ 5944 30.0 31.75835 AMPS WEIGHT ON BIT 44 @ 5976 -5 @ 6001 33.9 22.66674 KLBS ROTARY RPM 0 @ 6007 0 @ 5937 0.0 0.03693 RPM PUMP PRESSURE 2783 @ 5938 2482 @ 5997 2569.1 2526.44116 PSI DRILLING MUD REPORT DEPTH 5828 MW 9.1 VIS 54 PV 14 YP 26 FL 5.3 Gels 12/23/27 CL- 1300 FC 1/ SOL 5 SD 0.1 OIL 3/93 MBL 13 pH 9.6 Ca+ 40 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 326 @ 5983 103 @ 5968.00000 226.7 TRIP GAS 0 CUTTING GAS @ @ WIPER GAS 0 CHROMATOGRAPHY(ppm) SURVEY 0 METHANE(C-1) 52708 @ 5982 16122 @ 5966 36086.8 CONNECTION GAS HIGH 0 ETHANE(C-2) 877 @ 5982 215 @ 5966 582.8 AVG 226 PROPANE(C-3) 798 @ 5982 232 @ 5966 569.4 CURRENT 0 BUTANE(C-4) 1309 @ 6007 405 @ 5966 930.8 CURRENT BACKGROUND/AVG 0 PENTANE(C-5) 767 @ 6006 258 @ 5966 559.9 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION SAND=OLIVE GRAY TO LIGHT OLIVE GRAY;UPPER FINE TO LOWER FINE,OCCASIONAL LOWER MEDIUM;SUB-PRISMOIDAL TO SUB-DISCOIDAL;ANGULAR TO SUB-ANGULAR;MODERATELY TO MODERATELY WELL SORTED;UNCONSOLIDATED SAND;GRAIN LITHOLOGY SUPPORTED;TRANSLUCENT QUARTZ;LIGHT GREEN LITHICS,DISSEMINATED PYRITE AND PALE YELLOWISH ORANGE SHELL FRAGMENTS;STRONG OIL ODOR;50%GRAINS DARK BROWN STAIN;75%SAMPLE FLUORESCES BRIGHT YELLOW GOLD; IMMEDIATE BLOOMING BRIGHT WHITE FLUORESCENT CUT;LIGHT AMBER CUT;LIGHT BROWN RESIDUAL CUT;BRIGHT WHITE RESIDUAL FLUORESCENCE;FREE OIL ON SHAKERS AND IN POSSUM BELLY. PRESENT SAND 100% LITHOLOGY DAILY ACTIVITY ROTARY DRILL FROM 5936'TO 6007';CIRUCLATE BOTTUMS UP EIGHT TIMES;TRIP OUT OF HOLE;CHANGE RAMS;TEST SUMMARY BOPS;RIG UP TO RUN CASING 9 5/8"CASING;RUN 9 5/8"CASING. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML$3045, RIGWATCH$1450 REPORT BY TOLLEF WINSLOW file://C:\Documents and Settings\EpochAdmin\My Documents\My Wells\ENI\OIl 1-0... Daily Report ENI Petroleum Nikaitchuq DAILY WELLSITE REPORT El EPOCH 01 11-01 REPORT FOR Goerlich/Longo/Buchanan DATE Oct 03,2010 DEPTH 6007' PRESENT OPERATION Pick up 5"drill pipe TIME 24:00:00 YESTERDAY 6007' 24 HOUR FOOTAGE 0' CASING INFORMATION 20"@ 160' 13 3/8"@ 2334'9 5/8"@ 5991' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 5923.86 76.79 341.85 3638.61 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 12 1/4" Hughes MLX-1X 5172120 1x20,2x18,1 by 16 5016' 6007' 991' 10.5 2-2-WT-A-E-2-NO-TD TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION NA @ NA @ NA NA FT/HR SURFACE TORQUE NA @ NA @ NA NA AMPS WEIGHT ON BIT NA @ NA @ NA NA KLBS ROTARY RPM NA @ NA @ NA NA RPM PUMP PRESSURE NA @ NA @ NA NA PSI DRILLING MUD REPORT DEPTH 6007' MW 9.1 VIS - PV 10 YP 13 FL - Gels 5/9/- CL- - FC - SOL - SD - OIL - MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL NA TO TOOLS NA GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS NA @ NA @ NA TRIP GAS- CUTTING GAS NA @ NA @ NA WIPER GAS- CHROMATOGRAPHY(ppm) SURVEY- METHANE(C-1) NA @ NA @ NA CONNECTION GAS HIGH- ETHANE(C-2) NA @ NA @ NA AVG- PROPANE(C-3) NA @ NA @ NA CURRENT- BUTANE(C-4) NA @ NA @ NA CURRENT BACKGROUND/AVG 0 PENTANE(C-5) NA @ NA @ NA HYDROCARBON SHOWS NA INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sand PRESENT LITHOLOGY Sand 100% DAILY ACTIVITY Continue running in hole with 9 5/8"casing.Run casing to TD at 5991'md.Circulate 2 bottoms up then pump cement.Set and test pack SUMMARY off.Change and test rams.Clean pits and prep to pick up 5"drill pipe as of midnight. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML-$3045; RigWatch -$1450 REPORT BY Z. Beekman file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY ... Daily Report ENI Petroleum Nikaitchuq DAILY WELLSITE REPORT PI EPOCH OI 11-01 REPORT FOR Goerlich/LongoBuchanan DATE Oct 4,2010 DEPTH 6007' PRESENT OPERATION Drilling Out Cement TIME 24:00:00 YESTERDAY 6007' 24 HOUR FOOTAGE 0' CASING INFORMATION 20"@ 160' 13 3/8"@ 2334'9 5/8"@ 5991' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 5923.86 76.79 341.85 3638.61 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 5 8 1/2" Hycalog RSR616M-F8 226446 6x12 6007' - - - - - RR4 121/4" Hughes MLX-1X 5172120 1x20,2x18,1x16 5016' 6007' 991' 10.5 2-2-WT-A-E-2-NO-TD TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION NA @ NA @ NA NA FT/HR SURFACE TORQUE NA @ NA @ NA NA AMPS WEIGHT ON BIT NA @ NA @ NA NA KLBS ROTARY RPM NA @ NA @ NA NA RPM PUMP PRESSURE NA @ NA @ NA NA PSI DRILLING MUD REPORT DEPTH 6007' MW 8.7 VIS - PV 16 YP 24 FL - Gels 10/11/- CL- 49500 FC - SOL 6.19 SD - OIL 60/40 MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL NA TO NA TOOLS NA GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS NA @ NA @ NA TRIP GAS- CUTTING GAS NA @ NA @ NA WIPER GAS- CHROMATOGRAPHY(ppm) SURVEY- METHANE(C-1) NA © NA @ NA CONNECTION GAS HIGH - ETHANE(C-2) NA @ NA © NA AVG- PROPANE(C-3) NA © NA @ NA CURRENT- BUTANE(C-4) NA © NA @ NA CURRENT BACKGROUND/AVG 0 PENTANE(C-5) NA @ NA @ NA HYDROCARBON SHOWS NA INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sand PRESENT LITHOLOGY Sand 100% DAILY ACTIVITY Continue picking 5"drill pipe and rack back stands.Pick up BHA#6.Run in hole and shallow test tools.Trip in hole to 2300'and log SUMMARY cement bonding.Run casing pressure test.Circulate bottoms up and displace mud and prepare to drill out cement as of midnight. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML-$3060; RigWatch-$1450 REPORT BY Z. Beekman file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY ... Daily Report ENI Petroleum Nikaitchuq DAILY WELLSITE REPORT PI EPOCH .1,1-01 REPORT FOR Goerlich/Longo/Buchanan DATE Oct 05,2010 DEPTH 6976' PRESENT OPERATION Prep Open Hole Sidetrack TIME 24:00:00 YESTERDAY 6007' 24 HOUR FOOTAGE 969' CASING INFORMATION 20"@ 160' 13 3/8"@ 2334'9 5/8"@ 5991' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 5 8 1/2" Hycalog RST616M-F8 226446 6x12 6007' - 969' - - DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 394.4 @ 6577.00000 14.0 @ 6155.00000 171.4 202.06880 FT/HR SURFACE TORQUE 9959 @ 6184.00000 31 @ 6007.00000 6801.8 7529.82324 AMPS WEIGHT ON BIT 22 @ 6007.00000 -3 @ 6028.00000 6.1 12.90726 KLBS ROTARY RPM 131 @ 6196.00000 0 @ 6007.00000 115.5 128.49123 RPM PUMP PRESSURE 2718 @ 6975.00000 1553 @ 6128.00000 2162.9 2718.07861 PSI DRILLING MUD REPORT DEPTH 6977 MW 8.6 VIS - PV 16 YP 36 FL 6.7 Gels 16/16/16 CL- 50000 FC -/2 SOL 2.68 SD - OIL 60/40 MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL 6007'TO 6977' TOOLS Gamma,Resistivity,Pressure While Drilling,Sonic GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 672 @ 6201.00000 20 @ 6020.00000 292.9 TRIP GAS- CUTTING GAS 0 @ 6976.00000 0 @ 6976.00000 0.0 WIPER GAS- CHROMATOGRAPHY(ppm) SURVEY- METHANE(C-1) 133544 @ 6540.00000 3219 @ 6240.00000 50500.2 CONNECTION GAS HIGH 52 ETHANE(C-2) 9177 @ 6341.00000 26 @ 6240.00000 571.0 AVG 36 PROPANE(C-3) 996 @ 6010.00000 10 @ 6240.00000 208.6 CURRENT- BUTANE(C-4) 1689 @ 6010.00000 10 @ 6240.00000 266.8 CURRENT BACKGROUND/AVG 2/95 PENTANE(C-5) 956 @ 6010.00000 4 @ 6240.00000 134.5 HYDROCARBON SHOWS NA INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Siltstone;Sandy Siltstone/Silty Sandstone PRESENT LITHOLOGY Siltstone 60%,Sand 30%,Sandstone 10% DAILY ACTIVITY Continue displacing oil based mud.Drill out of 9 5/8"shoe at 6007'and drill 20ft of new hole to 6027'.Circulate bottoms up.Reciprocate SUMMARY pipe.Perform successful LOT to EMW of 12.84ppg.Drill ahead from 6027'to 6977'md.Trip back to 6416'and begin troughing for open hole sidetrack as of midnight. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML-$3060; Rig Watch-$1450 REPORT BY Z. Beekman file://C:\Documents and Settings\EpochAdmin\MVly Documents\MVly Wells\ENI\201010... Daily Report ENI Petroleum Nikaitchuq DAILY WELLSITE REPORT El EPOCH .1 11-01 REPORT FOR Goerlich/Longo/Buchanan DATE Oct 6,2010 DEPTH 7283' PRESENT OPERATION Drilling TIME 24:00:00 YESTERDAY 6357' 24 HOUR FOOTAGE 936' CASING INFORMATION 20"@ 160' 13 3/8"@ 2334'9 5/8"@ 5991' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 7181.15 88.37 331.24 3682.25 SURVEY DATA 7086.27 89.94 330.7 3680.86 6990.01 88.03 332.77 3679.15 6893.3 88.03 334.76 3675.83 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 5 8 1/2" Hycalog RSR616M-F8 226446 6x12 6007' - 2246' 13.1 - - DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 229.8 @ 7060.00000 14.5 @ 6434.00000 161.7 170.16277 FT/HR SURFACE TORQUE 11383 @ 6760.00000 5916 @ 6408.00000 7682.2 8232.84277 AMPS WEIGHT ON BIT 18 @ 6384.00000 0 @ 6394.00000 6.8 8.53638 KLBS ROTARY RPM 130 @ 6668.00000 60 @ 6433.00000 119.9 128.33379 RPM PUMP PRESSURE 2404 @ 6640.00000 1706 @ 6466.00000 2271.3 2378.08447 PSI DRILLING MUD REPORT DEPTH 7283' MW 8.7 VIS - PV 15 YP 21 FL 6.0 Gels 9/9/9 CL- 42000 FC -/2 SOL 6.47 SD - OIL 65/35 MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL 6357'TO 7283' TOOLS Gamma,Resistivity,Pressure While Drilling,Sonic GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 400 @ 6769.00000 2 @ 7026.00000 170.7 TRIP GAS- CUTTING GAS 0 @ 7149.00000 0 @ 7149.00000 0.0 WIPER GAS- CHROMATOGRAPHY(ppm) SURVEY- METHANE(C-1) 81947 @ 7107.00000 577 @ 7026.00000 34204.8 CONNECTION GAS HIGH - ETHANE(C-2) 2158 @ 6357.00000 5 @ 7026.00000 305.2 AVG - PROPANE(C-3) 303 @ 6359.00000 2 @ 7026.00000 134.2 CURRENT 0 BUTANE(C-4) 748 @ 6451.00000 3 @ 7026.00000 186.6 CURRENT BACKGROUND/AVG 20/275 PENTANE(C-5) 270 @ 6451.00000 1 @ 6862.00000 95.8 HYDROCARBON 1)5400-5680;2)5880-6007 SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 1)5400-5680 2) 1)Sand/Conglomeratic 1)Max 1)medium to medium light gray with a moderate brownish secondary hue;soft to dis-aggregated; 5880-6007 Sand 2)Sand Gas of moderately well to poorly sorted;medium lower to fine upper in the top of the zone grading to medium 375u upper and coarse at depth;scattered to abundant very coarse and pebble fragments;Predominantly 2)Max translucent white to light gray quartz;30 to 40%light to medium gray lithics;common to abundant light Gas of blue-gray lithics;common to abundant pyrite;trace orange jasper;trace tan to off white shell fragments; 659u occasional very thin coal interbeds;10 to 40%visible oil stain;slight oil odor;30 to 90%dull gold sample fluorescence;fast streaming cut to blue-white;good brown residue ring;medium gold residue fluorescence cuts immediately to blue white;slightly calcareous.2)Sand;olive gray to light olive gray;upper fine to lower fine,occasional lower medium;sub-prismoidal to sub-discoidal;angular to sub-angular;moderately to moderately well sorted;unconsolidated sand;grain supported;translucent quartz;light green lithics; disseminated pyrite and pale yellowish orange shell fragments;strong oil odor;50%grains dark brown stain;75%sample fluorescence bright yellow gold;immediat blooming bright white fluorescence cut;light amber cut;light brown residual cut;bright white residual fluorescence;free oil on shakers and in possum belly. LITHOLOGY Sand,Sandstone PRESENT LITHOLOGY Sand 50%,Sandstone 50% DAILY ACTIVITY Started building trough for open hole sidetrack from 6378'to 6403'.Serviced top drive due mechanical failure and not rotating.Racked SUMMARY back one stand and to trough at 6327'to 6357'.Drill ahead from kick off point of 6357'to current depth as of midnight. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML-$3060; RigWatch -$1450 file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\IVIY DOCUMENTS\MY ... Daily Report REPORT BY Z. Beekman file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY ... Daily Report ENI Petroleum Nikaitchuq DAILY WELLSITE REPORT PI EPOCH OI 11-01 REPORT FOR Goerlich/Longo/Buchanan DATE Oct 7,2010 DEPTH 9310' PRESENT OPERATION Drilling TIME 24:00:00 YESTERDAY 7283' 24 HOUR FOOTAGE 2027' CASING INFORMATION 20"@ 160' 13 3/8"@ 2334'9 5/8"@ 5991' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 9478.86 91.77 304.19 3695.6 SURVEY DATA 9383.71 93.92 304.64 3700.32 9288.52 95.2 304.7 3707.88 9192.69 95.86 303.83 3717.12 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 5 8 1/2" Hycalog RSR616M-F8 226446 6x12 6007' - 4273' 28.3 - - DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 267.8 @ 8399.00000 12.3 @ 8374.00000 153.9 14.93303 FT/HR SURFACE TORQUE 14711 @ 8424.00000 7130 @ 7532.00000 9750.1 13178.43555 AMPS WEIGHT ON BIT 24 @ 8264.00000 0 @ 8789.00000 8.5 13.77730 KLBS ROTARY RPM 131 @ 8779.00000 65 @ 8445.00000 127.1 82.44157 RPM PUMP PRESSURE 2767 @ 9171.00000 676 @ 7842.00000 2524.6 2714.18481 PSI DRILLING MUD REPORT DEPTH 9310' MW 8.7 VIS 50 PV 14 YP 16 FL 6.0 Gels 7/8/8 CL- 39000 FC -/2 SOL 6.39 SD - OIL 66/34 MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL 6007'TO 9310' TOOLS Gamma,Resistivity,Pressure While Drilling,Sonic GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 541 @ 8696.00000 1 @ 8932.00000 179.8 TRIP GAS - CUTTING GAS 0 @ 9310.00000 0 @ 9310.00000 0.0 WIPER GAS- CHROMATOGRAPHY(ppm) SURVEY- METHANE(C-1) 100217 @ 8306.00000 311 @ 8929.00000 32750.3 CONNECTION GAS HIGH 140 ETHANE(C-2) 3488 @ 8695.00000 2 @ 8929.00000 406.9 AVG 101 PROPANE(C-3) 3126 @ 8693.00000 0 @ 8929.00000 223.4 CURRENT 68 BUTANE(C-4) 6116 @ 8693.00000 0 @ 8932.00000 425.2 CURRENT BACKGROUND/AVG 6/120 PENTANE(C-5) 8631 @ 8693.00000 0 @ 8932.00000 464.7 HYDROCARBON SHOWS NA INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sand,Sandstone,Siltstone PRESENT LITHOLOGY Sand 50%,Sandstone 40%,Siltstone 10% DAILY ACTIVITY SUMMARY Continued drilling ahead from 7118'to current depth of 9310'md with no issues.Max gas for the day was 541 u at 8696'md. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML-$3060; RigWatch-$1450 REPORT BY Z. Beekman file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY ... Daily Report ENI Petroleum Nikaitchuq DAILY WELLSITE REPORT I EPOCH OI 11-01 REPORT FOR Goerlich/Longo/Buchanan DATE Oct 8,2010 DEPTH 10594' PRESENT OPERATION Pulling out of hole TIME 24:00:00 YESTERDAY 9310' 24 HOUR FOOTAGE 1284' CASING INFORMATION 20"@ 160' 13 3/8"@ 2334'9 5/8"@ 5991' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 10594.00 90.11 301.40 3687.96 SURVEY DATA 10528.76 90.11 301.40 3688.08 10433.89 90.09 302.67 3688.25 10340.65 91.11 304.81 3689.23 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 5 8 1/2" Hycalog RSR616M-F8 226446 6x12 6007' 10594' 5557' 33.5 - TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 2439.5 @ 9847.00000 11.4 @ 9311.00000 234.4 126.13400 FT/HR SURFACE TORQUE 15825 @ 9313.00000 8550 @ 9311.00000 11106.6 AMPS WEIGHT ON BIT 18 @ 9459.00000 1 @ 9822.00000 6.7 5.41800 KLBS ROTARY RPM 131 @ 9835.00000 79 @ 10359.00000 127.9 RPM PUMP PRESSURE 2995 @ 10433.00000 2103 @ 9326.00000 2778.6 PSI DRILLING MUD REPORT DEPTH 10594' MW 8.7 VIS 46 PV 13 YP 19 FL 5.8 Gels 7/7/8 CL- 40000 FC -/2 SOL 6.06 SD - OIL 65/35 MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL 6007'TO 10594' TOOLS Gamma,Resistivity,Pressure While Drilling,Sonic GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 512 @ 9982.00000 7 @ 9633.00000 211.0 TRIP GAS - CUTTING GAS 0 @ 10594.00000 0 @ 10594.00000 0.0 WIPER GAS - CHROMATOGRAPHY(ppm) SURVEY- METHANE(C-1) 104643 @ 9982.00000 1577 @ 9633.00000 45419.2 CONNECTION GAS HIGH 62 ETHANE(C-2) 728 @ 9983.00000 10 @ 9633.00000 319.7 AVG 58 PROPANE(C-3) 176 @ 10572.00000 2 @ 9633.00000 75.8 CURRENT 0 BUTANE(C-4) 405 @ 10574.00000 4 @ 9633.00000 140.3 CURRENT BACKGROUND/AVG 0/125 PENTANE(C-5) 421 @ 10574.00000 3 @ 9633.00000 120.8 HYDROCARBON SHOWS NA INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sand,Sandstone PRESENT LITHOLOGY Sand 80%,Sandstone 20% DAILY ACTIVITY Continue drilling ahead from 9310'to TD at 10594'md with no issues.Circulate 4+bottoms up and condition hole reciprocating pipe.Back SUMMARY ream out of hole from 10118'to 5918'.Circulate bottoms up inside casing.Pull out of hole on elevators. EPOCH PERSONNEL ON BOARD 4 DAILY COST DMI-$3060; RigWatch -$1450 REPORT BY Z. Beekman file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY ... Daily Report ENI Petroleum DAILY WELLSITE REPORT U EPOCH .1,1-01 REPORT FOR KEENER/SMITH DATE 9/21/2010 DEPTH 0 PRESENT OPERATION RIG UP BHA TIME 24:00:00 YESTERDAY 0 24 HOUR FOOTAGE 0 CASING INFORMATION 20"@ 160' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 120/120 MW 8.7 VIS 88 PV 10 YP 31 FL - Gels 23/26/29 CL- 1100 FC 3/- SOL 2.75 SD OIL /97 MBL 25 pH 9.3 Ca+ 40 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 0 CUTTING GAS @ @ WIPER GAS 0 CHROMATOGRAPHY(ppm) SURVEY 0 METHANE(C-1) @ @ CONNECTION GAS HIGH 0 ETHANE(C-2) @ @ AVG 0 PROPANE(C-3) @ @ CURRENT 0 BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG 0 PENTANE(C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY FINISH RIGGING UP RIG;PICK UP DRILL PIPE,INSTALL MOUSE HOLE IN ROTARY TABLE;PUCK UP DRILL PIPE AND RACK BACK;PUCK UP HEAVY WALL DRILL PIPE; SUMMARY RACK BACK;CALIBRATE CANRIG AND SLB BLOCKS. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML$3045,RIGWATCH$1450 REPORT BY TOLLEF WINSLOW file://C:\Documents and Settings\EpochAdmin\My Documents\My Wells\ENI\OI1 1-01\Daily Reports... Daily Report ENI Petroleum Nikaitchuq DAILY WELLSITE REPORT El EPOCH OI 11-01 REPORT FOR Goerlich/Longo/Buchanan DATE Oct.9,2010 DEPTH 10594' PRESENT OPERATION Trip in hole for displacement TIME 24:00:00 YESTERDAY 10594' 24 HOUR FOOTAGE 0' CASING INFORMATION 20"@ 160' 13 3/8"@ 2334'9 5/8"@ 5991' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 10594.00 90.15 301.55 3687.62 SURVEY DATA 10528.73 90.15 301.55 3687.79 10433.89 90.12 302.78 3688.01 10340.63 91.15 304.91 3689.04 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 8 1/2" Hycalog RSR616M-F8 226446 6x12 6007' 10594' 4587' 33.5 TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION NA @ NA @ NA NA FT/HR SURFACE TORQUE NA @ NA @ NA NA AMPS WEIGHT ON BIT NA @ NA @ NA NA KLBS ROTARY RPM NA @ NA @ NA NA RPM PUMP PRESSURE NA @ NA @ NA NA PSI DRILLING MUD REPORT DEPTH 10594' MW 8.7 VIS 50 PV 13 YP 20 FL 6.0 Gels 8/8/9 CL- 40000 FC -/2 SOL 6.36 SD - OIL 65/35 MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL NA TO NA TOOLS NA GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS NA @ NA @ NA TRIP GAS- CUTTING GAS NA @ NA @ NA WIPER GAS- CHROMATOGRAPHY(ppm) SURVEY- METHANE(C-1) NA @ NA @ NA CONNECTION GAS HIGH - ETHANE(C-2) NA @ NA @ NA AVG - PROPANE(C-3) NA @ NA @ NA CURRENT- BUTANE(C-4) NA @ NA @ NA CURRENT BACKGROUND/AVG 0/- PENTANE(C-5) NA @ NA @ NA HYDROCARBON SHOWS NA INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sand,Sandstone PRESENT LITHOLOGY Sand 80%,Sandstone 20% DAILY ACTIVITY Circulate 3 bottoms up inside shoe.Continue tripping out of hole from 5910'to 477'.Lay down BHA.Service top drive and perform SUMMARY BOP test.Pick up BHA and begin tripping in hole. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML-$3060; RigWatch -$1450 REPORT BY Z. Beekman file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY ... Daily Report ENI Petroleum Nikaitchuq DAILY WELLSITE REPORT El EPOCH 01 11-01 REPORT FOR Goerlich/Longo/Buchanan DATE Oct 10,2010 DEPTH 10594' PRESENT OPERATION POOH to shoe TIME 24:00:00 YESTERDAY 10594' 24 HOUR FOOTAGE 0' CASING INFORMATION 20"@ 160' 13 3/8"@ 2334'9 5/8"@ 5991 DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 10594.00 90.15 301.55 3687.62 SURVEY DATA 10528.73 90.15 301.55 3687.79 10433.89 90.12 302.78 3688.01 10340.63 91.15 304.91 3689.04 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 8 1/2" Hycalog RSR616M-F8 226446 6x12 6007' 10594' 4587' 33.5 2-2-WT-A-X-I-CT-TD - DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION NA @ NA @ NA NA FT/HR SURFACE TOROUE NA @ NA @ NA NA AMPS WEIGHT ON BIT NA @ NA @ NA NA KLBS ROTARY RPM NA @ NA @ NA NA RPM PUMP PRESSURE NA @ NA @ NA NA PSI DRILLING MUD REPORT DEPTH 10594' MW 9.1 VIS - PV 17 YP 22 FL 6.0 Gels 8/8/8 CL- 44000 FC -/2 SOL 10.39 SD - OIL 64/36 MBL - pH - Ca+ - CCI - I MWD SUMMARY INTERVAL NA TO NA TOOLS NA GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS NA @ NA @ NA TRIP GAS - CUTTING GAS NA @ NA @ NA WIPER GAS 67 CHROMATOGRAPHY(ppm) SURVEY- METHANE(C-1) NA @ NA @ NA CONNECTION GAS HIGH - ETHANE(C-2) NA @ NA @ NA AVG - PROPANE(C-3) NA @ NA @ NA CURRENT- BUTANE(C-4) NA @ NA @ NA CURRENT BACKGROUND/AVG - PENTANE(C-5) NA @ NA @ NA HYDROCARBON SHOWS NA INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sand,Sandstone PRESENT LITHOLOGY Sand 80%,Sandstone 20% DAILY ACTIVITY Trip in hole from 2718'to 5942'.Cut and slip drill line.Trip in hole from 5942'to 10594'.Tight spots at 6978'-6996',7570'-7819',8683'-8815', SUMMARY 9468'-9485',and 9677-10155'.Circulate 1.5 bottoms up and pump sweep.Pull out of hole from 10594'to 10347'.Back ream out of hole from 10347'to 9000'.Circulate 3 bottoms up.Pull out of hole to 8241'as of midnight with tight spot at 8625'. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML-$3060; RigWatch -$1450 REPORT BY Z. Beekman file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY ... Daily Report ENI Petroleum Nikaitchuq DAILY WELLSITE REPORT El EPOCH 01 11-01 REPORT FOR Goerlich/Longo/Buchanan DATE Oct 11,2010 DEPTH 10594' PRESENT OPERATION Lay down BHA TIME 24:00:00 YESTERDAY 10594' 24 HOUR FOOTAGE 0' CASING INFORMATION 20"@ 160' 13 3/8"@ 2334'9 5/8"@ 5991 DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 10594.00 90.15 301.55 3687.62 SURVEY DATA 10528.73 90.15 301.55 3687.79 10433.89 90.12 302.78 3688.01 10340.63 91.15 304.91 3689.04 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 5 8 1/2" Hycalog RSR616M-F8 226446 6x12 6007' 10594' 4587' 33.5 2-2-WT-A-X-I-CT-TD TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION NA @ NA @ NA NA FT/HR SURFACE TORQUE NA @ NA @ NA NA AMPS WEIGHT ON BIT NA @ NA @ NA NA KLBS ROTARY RPM NA @ NA @ NA NA RPM PUMP PRESSURE NA @ NA @ NA NA PSI DRILLING MUD REPORT DEPTH 10594' MW 9.1 VIS 51 PV 18 YP 19 FL 6.0 Gels 8/9/9 CL- 44000 FC -/2 SOL 10.39 SD - OIL 64/36 MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL NA TO NA TOOLS NA GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS NA @ NA @ NA TRIP GAS 0 CUTTING GAS NA @ NA @ NA WIPER GAS 0 CHROMATOGRAPHY(ppm) SURVEY- METHANE(C-1) NA @ NA @ NA CONNECTION GAS HIGH - ETHANE(C-2) NA @ NA @ NA AVG - PROPANE(C-3) NA @ NA @ NA CURRENT- BUTANE(C-4) NA @ NA @ NA CURRENT BACKGROUND/AVG 0/0 PENTANE(C-5) NA @ NA @ NA HYDROCARBON SHOWS NA INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sand,Sandstone PRESENT LITHOLOGY Sand 80%,Sandstone 20% DAILY ACTIVITY Continue back reaming from 8241'.Pull out of hole on elevators from 8241'to shoe with a tight spot at 6447'.Run in hole on elevators. SUMMARY Circulate 7 bottoms up.Pull out of hole on elevators and lay down BHA. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML-$3060; RlgWatch -$1450 REPORT BY Z. Beekman file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY ... Daily Report EM Petroleum Nikaitchuq DAILY WELLSITE REPORT HI EPOCH 01 11-01 REPORT FOR Goerlich/Longo/Buchanan DATE Oct 12,2010 DEPTH 10594' PRESENT OPERATION Pulling out of hole/lay down DP TIME 24:00:00 YESTERDAY 10594' 24 HOUR FOOTAGE 0' CASING INFORMATION 13 3/8"@ 2334'9 5/8"@ 5991'5.5"liner @ 10594' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 10594.00 90.15 301.55 3687.62 SURVEY DATA 10528.73 90.15 301.55 3687.79 10433.89 90.12 302.78 3688.01 10340.63 91.15 304.91 3689.04 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION NA @ NA @ NA NA FT/HR SURFACE TORQUE NA @ NA @ NA NA AMPS WEIGHT ON BIT NA @ NA @ NA NA KLBS ROTARY RPM NA @ NA @ NA NA RPM PUMP PRESSURE NA @ NA @ NA NA PSI DRILLING MUD REPORT DEPTH 10594' MW 9.1 VIS 52 PV 18 YP 19 FL 6.0 Gels 8/9/9 CL- 44000 FC -/2 SOL 9.39 SD OIL 63/37 MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL NA TO NA TOOLS NA GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS NA @ NA @ NA TRIP GAS - CUTTING GAS NA @ NA @ NA WIPER GAS - CHROMATOGRAPHY(ppm) SURVEY- METHANE(C-1) NA @ NA @ NA CONNECTION GAS HIGH - ETHANE(C-2) NA @ NA @ NA AVG- PROPANE(C-3) NA @ NA @ NA CURRENT- BUTANE(C-4) NA @ NA @ NA CURRENT BACKGROUND/AVG 0/0 PENTANE(C-5) @ NA @ NA HYDROCARBON SHOWS NA INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sand,Sandstone PRESENT LITHOLOGY Sand 80%,Sandstone 20% DAILY ACTIVITY Run in hole with 5 1/2"liner.Tag bottom at 10599'and set liner at 10594'.Circulate 4 bottoms up and drop ball.Test packer for 10 SUMMARY minutes.Pull out of hole and lay down 90 joints of drill pipe. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML-$3060; RigWatch -$1450 REPORT BY Z. Beekman file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY ... Daily Report ENI Petroleum Nikaitchuq DAILY WELLSITE REPORT I EPOCH OI 11-01 REPORT FOR Goerlich/Longo/Buchanan DATE Oct 13,2010 DEPTH 10594' PRESENT OPERATION Wireline Logging TIME 24:00:00 YESTERDAY 10594' 24 HOUR FOOTAGE 0' CASING INFORMATION 13 3/8"@ 2334'9 5/8"@ 5991'5 1/2"liner @ 10594' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 10594.00 90.15 301.55 3687.62 SURVEY DATA 10528.73 90.15 301.55 3687.79 10433.89 90.12 302.78 3688.01 10340.63 91.15 304.91 3689.04 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION NA @ NA @ NA NA FT/HR SURFACE TORQUE NA @ NA @ NA NA AMPS WEIGHT ON BIT NA @ NA @ NA NA KLBS ROTARY RPM NA @ NA @ NA NA RPM PUMP PRESSURE NA @ NA @ NA NA PSI DRILLING MUD REPORT DEPTH 10594' MW 9.0 VIS - PV - YP - FL - Gels - CL- - FC - SOL - SD - OIL - MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL NA TO NA TOOLS NA GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS NA @ NA @ NA TRIP GAS - CUTTING GAS NA @ NA @ NA WIPER GAS - CHROMATOGRAPHY(ppm) SURVEY- METHANE(C-1) NA @ NA @ NA CONNECTION GAS HIGH - ETHANE(C-2) NA @ NA @ NA AVG - I PROPANE(C-3) NA @ NA @ NA CURRENT- BUTANE(C-4) NA @ NA @ NA CURRENT BACKGROUND/AVG 0/0 PENTANE(C-5) NA @ NA @ NA HYDROCARBON SHOWS NA INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sand,Sandstone PRESENT LITHOLOGY Sand 80%,Sandstone 20% DAILY ACTIVITY Continue laying down drill pipe.Lay down liner running tool.Run in hole to 5769'and displace to 9.0 ppg brine.Clean pits and shakers. SUMMARY Circulate and condition well out of balance.Lay down remaining drill pipe and run wireline logs. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML-$3060; RigWatch -$1450 REPORT BY Z. Beekman II file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY ... Daily Report ENI Petroleum Nikaitchuq DAILY WELLSITE REPORT El EPOCH .1 11-01 REPORT FOR Goerlich/Longo/Buchanan DATE Oct 14,2010 DEPTH 10594' PRESENT OPERATION Running Tubing TIME 24:00:00 YESTERDAY 10594' 24 HOUR FOOTAGE 0 CASING INFORMATION 13 3/8"@ 2334'9 5/8"@ 5991'5 1/2"liner @ 10594' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 10594.00 90.15 301.55 3687.62 SURVEY DATA 10528.73 90.15 301.55 3687.79 10433.89 90.12 302.78 3688.01 10340.63 91.15 304.91 3689.04 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION NA @ NA @ NA NA FT/HR SURFACE TORQUE NA @ NA @ NA NA AMPS WEIGHT ON BIT NA @ NA @ NA NA KLBS ROTARY RPM NA @ NA @ NA NA RPM PUMP PRESSURE NA @ NA @ NA NA PSI DRILLING MUD REPORT DEPTH 10594' MW 9.0 VIS - PV - YP - FL - Gels - CL- - FC - SOL - SD - OIL - MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL NA TO NA TOOLS NA GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS NA @ NA @ NA TRIP GAS - CUTTING GAS NA @ NA @ NA WIPER GAS - CHROMATOGRAPHY(ppm) SURVEY- METHANE(C-1) NA @ NA @ NA CONNECTION GAS HIGH- ETHANE(C-2) NA @ NA @ NA AVG - PROPANE(C-3) NA @ NA @ NA CURRENT- BUTANE(C-4) NA @ NA @ NA CURRENT BACKGROUND/AVG 0/0 PENTANE(C-5) NA @ NA @ NA HYDROCARBON SHOWS NA INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sand,Sandstone PRESENT LITHOLOGY Sand 80%,Sandstone 20% DAILY ACTIVITY Continued to run cased hole wire line logs.Lay down logging tools and pull wear ring.Rig up to run tubing.Pick up completion assembly SUMMARY and run in hole with 3 1/2"tubing to 2337'as of midnight. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML-$3060; RigWatch-$1450 REPORT BY Z. Beekman .c;io•((riAn,,,,,,,,,,o.,+n „...a co++;,..,.-.VC..,.,.t, A,a,...;...vn„,1,+,....\'1/11(11(11c L.+.... Daily Report ENI Petroleum Nikaitchuq DAILY WELLSITE REPORT El EPOCH OI 11-01 REPORT FOR Goerlich/LongoBuchanan DATE Oct 15,2010 DEPTH 10594' PRESENT OPERATION RIH w/3.5"completion tubing TIME 24:00:00 YESTERDAY 10594' 24 HOUR FOOTAGE 0' CASING INFORMATION 13 3/8"@ 2334 9 5/8"@ 5991 5 1/2"liner @ 10594 DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 10594.00 90.15 301.55 3687.62 SURVEY DATA 10528.73 90.15 301.55 3687.79 10433.89 90.12 302.78 3688.01 10340.63 91.15 304.91 3689.04 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION NA @ NA @ NA NA FT/HR SURFACE TORQUE NA @ NA @ NA NA AMPS WEIGHT ON BIT NA @ NA @ NA NA KLBS ROTARY RPM NA @ NA @ NA NA RPM PUMP PRESSURE NA @ NA @ NA NA PSI DRILLING MUD REPORT DEPTH 10594 MW 9.0 VIS - PV - YP - FL - Gels - CL- - FC - SOL - SD - OIL - MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL NA TO NA TOOLS NA GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS NA @ NA @ NA TRIP GAS - CUTTING GAS NA @ NA @ NA WIPER GAS - CHROMATOGRAPHY(ppm) SURVEY- METHANE(C-1) NA @ NA @ NA CONNECTION GAS HIGH- ETHANE(C-2) NA @ NA @ NA AVG- PROPANE(C-3) NA @ NA @ NA CURRENT- BUTANE(C-4) NA @ NA @ NA CURRENT BACKGROUND/AVG 0/0 PENTANE(C-5) NA @ NA @ NA HYDROCARBON SHOWS NA INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sand,Sandstone PRESENT LITHOLOGY Sand 80%,Sandstone 20% DAILY ACTIVITY SUMMARY Continueing to run 3 1/2"completion tubing.At a current depth of 7134'as of midnight. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML-$3060; RigWatch -$1450 REPORT BY Z. Beekman file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\DESKTOP\ENI\20101016... Daily Report ENI Petroleum Nikaitchuq DAILY WELLSITE REPORT I E POCH OI 11-01 REPORT FOR Keener/Longo/Buchanan DATE Oct 16,2010 DEPTH 10594' PRESENT OPERATION Nipple down BOP's TIME 24:00:00 YESTERDAY 10594' 24 HOUR FOOTAGE 0' CASING INFORMATION 13 3/8"@ 2334'9 5/8"@ 5991'5 1/2"liner @ 10594' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 10594.00 90.15 301.55 3687.62 SURVEY DATA 10528.73 90.15 301.55 3687.79 10433.89 90.12 302.78 3688.01 10340.63 91.15 304.91 3689.04 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION NA @ NA @ NA NA FT/HR SURFACE TORQUE NA @ NA @ NA NA AMPS WEIGHT ON BIT NA @ NA @ NA NA KLBS ROTARY RPM NA @ NA @ NA NA RPM PUMP PRESSURE NA @ NA @ NA NA PSI DRILLING MUD REPORT DEPTH 10594' MW 9.0 VIS - PV - YP - FL - Gels - CL- - FC - SOL - SD - OIL - MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL NA TO NA TOOLS NA GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS NA @ NA @ NA TRIP GAS - CUTTING GAS NA @ NA @ NA WIPER GAS - CHROMATOGRAPHY(ppm) SURVEY- METHANE(C-1) NA @ NA @ NA CONNECTION GAS HIGH - ETHANE(C-2) NA @ NA @ NA AVG- PROPANE(C-3) NA @ NA @ NA CURRENT- BUTANE(C-4) NA @ NA @ NA CURRENT BACKGROUND/AVG 0/0 PENTANE(C-5) NA @ NA @ NA HYDROCARBON SHOWS NA INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sand,Sandstone PRESENT LITHOLOGY Sand 80%,Sandstone 20% DAILY ACTIVITY Run 4 1/2"completion tubing.Test fiber optics.Land tubing hanger.Test well head and set packer.Test completion tubing to 4000 psi SUMMARY for 30 minutes.Nipple down BOP's. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML-$3060; RigWatch -$1450 REPORT BY Z. Beekman file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\DESKTOP\ENI\20101017... Daily Report ENI Petroleum Nikaitchuq DAILY WELLSITE REPORT El EPOCH OI 11-01 REPORT FOR Keener/Longo/Buchanan DATE Oct 17,2010 DEPTH 10594' PRESENT OPERATION Rig Move TIME 24:00:00 YESTERDAY 10594' 24 HOUR FOOTAGE 0' CASING INFORMATION 13 3/8"@ 2334'9 5/8"@ 5991'5 1/2"liner @ 10594' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 10594.00 90.15 301.55 3687.62 SURVEY DATA 10528.73 90.15 301.55 3687.79 10433.89 90.12 302.78 3688.01 10340.63 91.15 304.91 3689.04 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION NA @ NA @ NA NA FT/HR SURFACE TORQUE NA @ NA @ NA NA AMPS WEIGHT ON BIT NA @ NA @ NA NA KLBS ROTARY RPM NA @ NA @ NA NA RPM PUMP PRESSURE NA @ NA @ NA NA PSI DRILLING MUD REPORT DEPTH 10594' MW 9.0 VIS - PV - YP - FL - Gels - CL- - FC - SOL - SD - OIL - MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL NA TO NA TOOLS NA GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS NA @ NA @ NA TRIP GAS - CUTTING GAS NA @ NA @ NA WIPER GAS - CHROMATOGRAPHY(ppm) SURVEY- METHANE(C-1) NA @ NA @ NA CONNECTION GAS HIGH - I ETHANE(C-2) NA @ NA @ NA AVG- PROPANE(C-3) NA @ NA @ NA CURRENT- BUTANE(C-4) NA @ NA @ NA CURRENT BACKGROUND/AVG 0/0 PENTANE(C-5) NA @ NA @ NA HYDROCARBON SHOWS NA INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sand,Sandstone PRESENT LITHOLOGY Sand 80%,Sandstone 20% DAILY ACTIVITY SUMMARY Nipple up BOP.Run BOP test.Serviced rig and prep rig for rig move.Begin rig move to different well. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML-$3060; RigWatch -$1450 REPORT BY Z. Beekman file://C:\Documents and Settings\EpochAdmin\My Documents\My Wells\ENI\OI11-0... Daily Report Page 1 of 1 ENS Petroleum DAILY WELLSITE REPORT H EPOCH .11-01 REPORT FOR KEENER/SMITH DATE Sep 22,2010 DEPTH 777 PRESENT OPERATION DRILLING AHEAD TIME 24:00:00 YESTERDAY 122 24 HOUR FOOTAGE 655 CASING INFORMATION 20"@ 160' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 731.83 6.55 346.96 731.31 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 16" SMITH XR+ PP7039 1x16 3x20 122' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 166.1 @ 434.00000 13.9 @ 709.00000 69.6 110.51786 FT/HR SURFACE TORQUE 3578 @ 620.00000 3 @ 659.00000 200.4 2177.90527 AMPS WEIGHT ON BIT 34 @ 592.00000 - @ 343.00000 8.4 12.43964 KLBS ROTARY RPM 42 @ 717.00000 - @ 547.00000 - 39.69179 RPM PUMP PRESSURE 862 @ 771.00000 402 @ 163.00000 480.0 849.89966 PSI DRILLING MUD REPORT DEPTH 680'/680' MW 8.9 VIS 82 PV 11 YP 30 FL 7.5 Gels 26/29/31 CL- 2500 FC 3/- SOL 4.5 SD 0.25 OIL -/96 MBL 31 pH 8.3 Ca+ 60 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 0 @ 777.00000 0 @ 777.00000 0.0 TRIP GAS 0 CUTTING GAS 0 @ 777.00000 0 @ 777.00000 0.0 WIPER GAS 0 CHROMATOGRAPHY(ppm) SURVEY 0 METHANE(C-1) 0 @ 777.00000 0 @ 777.00000 0.0 CONNECTION GAS HIGH 0 ETHANE(C-2) 0 @ 777.00000 0 @ 777.00000 0.0 AVG 0 i PROPANE(C-3) 0 @ 777.00000 0 @ 777.00000 0.0 CURRENT 0 BUTANE(C-4) 0 @ 777.00000 0 @ 777.00000 0.0 CURRENT BACKGROUND/AVG 0 PENTANE(C-5) 0 @ 777.00000 0 @ 777.00000 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY SAMPLING PROGRAM BEGINS @ 1000' PRESENT LITHOLOGY DAILY ACTIVITY PICK UP AND MAKE UP CONDUCTOR CLEAN OUT BHA;ROTARY DRILL FROM 122'TO 160'/CLEAN OUT CONDUCTOR;PICK UP BHA AND ORIENTATE GYRO DATA TOOL; ' SUMMARY ROTARY DRILL FROM 160'TO 342';TRIP OUT OF HOLE FROM 342'TO 158';PICK UP REMAINING BHA;ROTARY DRILL FROM 342'TO 77T. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML @3045,RIGWATCH$1450 REPORT BY TOLLEF WINSLOW 1 file://C:\Documents and Settings\EpochAdmin\My Documents\My Wells\ENI\OI11-01\Da... 9/23/2010 Daily Report ENI Petroleum DAILY WELLSITE REPORT El EPOCH OI 11-01 REPORT FOR KEENER/SMITH DATE Sep 23,2010 DEPTH 2311.00000 PRESENT OPERATION DRILLING TO TD OF 2347' TIME 24:00:00 YESTERDAY 777.00000 24 HOUR FOOTAGE 1534 CASING INFORMATION 20"@ 160' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 2267.28' 41.29 342.34 2109.90' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 16" SMITH XR+ PP7039 1x16 3x20 122' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 450.2 @ 1360.00000 27.6 @ 2113.00000 128.0 143.88254 FT/HR SURFACE TORQUE 13955 @ 1138.00000 17 @ 807.00000 1131.6 39.70553 AMPS WEIGHT ON BIT 35 @ 778.00000 0 @ 1896.00000 15.2 13.19806 KLBS ROTARY RPM 43 @ 1830.00000 0 @ 796.00000 12.1 0.08634 RPM PUMP PRESSURE 1736 @ 2176.00000 580 @ 815.00000 1229.9 1493.38855 PSI DRILLING MUD REPORT DEPTH 2119 MW 9.2 VIS 92 PV 18 YP 28 FL 5.8 Gels 23/33/41 CL- 2000 FC 2/- SOL 6 SD 0.25 OIL /94 MBL 30 pH 8.4 Ca+ 100 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 138 @ 2110.00000 0 © 1250.00000 31.3 TRIP GAS 0 CUTTING GAS 0 © 2311.00000 0 @ 2311.00000 0.0 WIPER GAS 0 CHROMATOGRAPHY(ppm) SURVEY 0 METHANE(C-1) 24196 @ 2096.00000 65 © 1250.00000 6369.6 CONNECTION GAS HIGH 0 ETHANE(C-2) 0 @ 2311.00000 0 © 2311.00000 0.0 AVG 31 PROPANE(C-3) 0 @ 2311.00000 0 © 2311.00000 0.0 CURRENT 28 BUTANE(C-4) 0 © 2311.00000 0 @ 2311.00000 0.0 CURRENT BACKGROUND/AVG 20 PENTANE(C-5) 0 @ 2311.00000 0 @ 2311.00000 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION SAND=DARK GRAY TO MEDIUM DARK GRAY;UPPER MEDIUM TO LOWER FINE GRAINS;SPHERICAL TO SUB-DISCOIDAL; ANGULAR TO SUB-ANGULAR;MODERATELY WELL SORTED;UNCONSOLIDATED SAND;GRAIN SUPPORTED;TEXTURALLY LITHOLOGY IMMATURE;COMPOSTIONALLY IMMATURE;TRANSLUCENT AND WHITE QUARTZ GRAINS WITH IMPACTING;CARBONACEOUS MATERIAL,GREEN LITHICS,OCCASIONAL PINKISH ORANGE LITHICS AND PYRITE;POROSITY AND PERMEABILITY VISUALLY GOOD;NO OIL INDICATORS. PRESENT SAND 900/0 CLAY 10 LITHOLOGY DAILY ACTIVITY ROTARY DRILL FROM 777'TO 1500',WOB=20K,GPM=600,ECD=9.68;ROTARY DRILL FROM 1500'TO 1915',WOB-20K,GPM SUMMARY =610,ECD=9.55;ROTARY DRILL FROM 1915'TO 2311',WOB 20K,GPM=750,ECD=9.91. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML$3045, RIGWATCH$1450 REPORT BY TOLLEF WINSLOW file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY ... Daily Report ENI Petroleum DAILY WELLSITE REPORT El EPOCH 01 11-01 REPORT FOR KEENER/GOERLICH DATE Sep 24,2010 DEPTH 2347' PRESENT OPERATION RUNNING 13 3/8"CASING TIME 24:00:00 YESTERDAY 2311' 24 HOUR FOOTAGE 36' CASING INFORMATION 20"@ 160' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 2267.28' 41.29 342.34 2109.90' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 16" SMITH XR+ PP7039 1x163x20 160' 2347' 2187' 24.0 2-2-WT-A-E-I-NO-TD TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 169.0 @ 2323' 43.3 @ 2339' 101.3 69.1 FT/HR SURFACE TORQUE 624 @ 2321' 36 @ 2320' 58.0 39.5 AMPS WEIGHT ON BIT 20 @ 2334' 11 @ 2312' 16.7 16.9 KLBS ROTARY RPM 0 @ 2318' 0 @ 2345' 0.1 0.06454 RPM PUMP PRESSURE 1590 @ 2334' 1443 @ 2338' 1545.8 1476.6 PSI DRILLING MUD REPORT DEPTH 2347'/2170' MW 9.3 VIS - PV 23 YP 17 FL 5.8 Gels 11/36/42 CL- 1900 FC 2/- SOL 7 SD 0.2 OIL /93 MBL 24 pH 7.3 Ca+ 80 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 30 @ 2324' 18 @ 2331' 27.8 TRIP GAS 0 CUTTING GAS @ @ WIPER GAS 253 POOH CHROMATOGRAPHY(ppm) SURVEY 0 METHANE(C-1) 6193 @ 2324' 3662 @ 2331' 5582.5 CONNECTION GAS HIGH 0 ETHANE(C-2) @ @ AVG 27 PROPANE(C-3) @ @ CURRENT 0 BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG 0 PENTANE(C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION SAND=DARK GRAY TO MEDIUM DARK GRAY;UPPER MEDIUM TO LOWER FINE GRAINS;SPHERICAL TO SUB-DISCOIDAL; ANGULAR TO SUB-ANGULAR;MODERATELY WELL SORTED;UNCONSOLIDATED SAND;GRAIN SUPPORTED;TEXTURALLY LITHOLOGY IMMATURE;COMPOSTIONALLY IMMATURE;TRANSLUCENT AND WHITE QUARTZ GRAINS WITH IMPACTING;CARBONACEOUS MATERIAL,GREEN LITHICS,OCCASIONAL PINKISH ORANGE LITHICS AND PYRITE;POROSITY AND PERMEABILITY VISUALLY GOOD;NO OIL INDICATORS. PRESENT SAND 900/0,CLAY 10 LITHOLOGY DAILY ACTIVITY ROTARY DRILL FROM 2311'TO 2347'(TD),WOB 20,GPM 650,ECD 9.78;CIRCULATE AND CONDITION(CBU);BACK REAM FROM SUMMARY 2348'TO 684';CIRCULATE AND CONDITION HOLE UNTIL CLEAN;TRIP IN HOLE FROM 684'TO 2347';CIRCULATE AND CONDITION, PUMP SWEEP;TRIP OUT OF HOLE FROM 2347'TO 216';LAY DOWN BHA;RIG UP TO RUN CASING;RUN CASING TO 590'. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML$3045, DML$1450 REPORT BY TOLLEF WINSLOW file://C:\Documents and Settings\EpochAdmin\IVly Documents\MVly Wells\EN1\OI11-0... Daily Report ENI Petroleum DAILY WELLSITE REPORT PI EPOCH 01 11-01 REPORT FOR KEENER/GOERLICH DATE Sep 25,2010 DEPTH 2347' PRESENT OPERATION NIPPLE UP BOP STACK. TIME 24:00:00 YESTERDAY 2347' 24 HOUR FOOTAGE 0' CASING INFORMATION 20"@ 160' 13 3/8"@ 2343' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 2267.28' 41.29 342.34 2109.90' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 16" SMITH XR+ PP7039 1x163x20 160' 2347' 2187' 20.0 2-2-WT-A-E-I-NO-TD TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 2347'/2170' MW 9.4 VIS - PV 14 YP 7 FL - Gels 2/2/3 CL- - FC - SOL - SD - OIL - MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 14 CUTTING GAS @ @ WIPER GAS 0 CHROMATOGRAPHY(ppm) SURVEY 0 METHANE(C-1) @ @ CONNECTION GAS HIGH 0 ETHANE(C-2) @ @ AVG 0 PROPANE(C-3) @ @ CURRENT 0 BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG 0 PENTANE(C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION SAND=DARK GRAY TO MEDIUM DARK GRAY;UPPER MEDIUM TO LOWER FINE GRAINS;SPHERICAL TO SUB-DISCOIDAL; ANGULAR TO SUB-ANGULAR;MODERATELY WELL SORTED;UNCONSOLIDATED SAND;GRAIN SUPPORTED;TEXTURALLY LITHOLOGY IMMATURE;COMPOSTIONALLY IMMATURE;TRANSLUCENT AND WHITE QUARTZ GRAINS WITH IMPACTING;CARBONACEOUS MATERIAL,GREEN LITHICS,OCCASIONAL PINKISH ORANGE LITHICS AND PYRITE;POROSITY AND PERMEABILITY VISUALLY GOOD;NO OIL INDICATORS. PRESENT SAND 90%,CLAY 10% LITHOLOGY DAILY ACTIVITY RUN CASING FROM 590'TO 2334';CIRCULATE AND CONDITION MUD;PUMP CEMENT;RUN CASING FLOATS,RIG DOWN SUMMARY CASING EQUIPMENT;NIPPLE DOWN DIVERTER SYSTEM,DRILLING HEAD ADAPTER;NIPPLE UP BOP STACK,CLEAN PITS. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML$3045, RIGWATCH$1450 REPORT BY TOLLEF WINSLOW file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY ... Daily Report ENI Petroleum El IEPOI}-1I DAILY WELLSITE REPORT 0111-01 REPORT FOR KEENER/GOERLICH DATE Sep 26,2010 DEPTH 2347' PRESENT OPERATION DRILLING CEMENT AND 20'FORMATION TIME 24:00:00 YESTERDAY 2347' 24 HOUR FOOTAGE 0' CASING INFORMATION 20"@ 160'13 3/8"@ 2334' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 2267.28' 41.29 342.34 2109.90' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 16" SMITH XR+ PP7039 1x16 3x20 160' 2347' 2187' 20.0 2-2-WT-A-E-I-NO-TD TD 2 12 1/4" HYCALOG MSX619SA2C 226208 6x16 2347' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 2360'/2175' MW 8.9 VIS 40 PV 5 YP 11 FL - Gels 5/5/6 CL- 900 FC 1/- SOL 2- SD - OIL 2/96 MBL 1 pH 9.5 Ca+ 60 CCI - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 0 CUTTING GAS @ @ WIPER GAS 0 CHROMATOGRAPHY(ppm) SURVEY 0 METHANE(C-1) @ @ CONNECTION GAS HIGH 0 ETHANE(C-2) @ @ AVG 0 PROPANE(C-3) @ @ CURRENT 0 BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG 0 PENTANE(C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION SAND=DARK GRAY TO MEDIUM DARK GRAY;UPPER MEDIUM TO LOWER FINE GRAINS;SPHERICAL TO SUB-DISCOIDAL;ANGULAR TO SUB-ANGULAR;MODERATELY WELL LITHOLOGY SORTED;UNCONSOLIDATED SAND;GRAIN SUPPORTED;TEXTURALLY IMMATURE;COMPOSTIONALLY IMMATURE;TRANSLUCENT AND WHITE QUARTZ GRAINS WITH IMPACTING;CARBONACEOUS MATERIAL,GREEN LITHICS,OCCASIONAL PINKISH ORANGE LITHICS AND PYRITE;POROSITY AND PERMEABILITY VISUALLY GOOD;NO OIL INDICATORS. PRESENT CEMENT 100% LITHOLOGY DAILY ACTIVITY NIPPLE UP BOPS,TEST BOPS,PICK UP BHA#3;RUN IN HOLE TO 1038',MAKE UP GHOST REAMER;SHALLOW TEST MWD TOOLS;TRIP IN HOLE;TAG CEMENT @ 2241'; SUMMARY CIRCULATE AND CONDITION MUD;PRESSURE TEST CASING/SHOT AT 2500 PSI;DRILL CEMENT FROM 2241'TO 2329';TAG SHOE @ 2331';DRILL SHOE;DRILL CEMENT. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML$3045,RIG WATCH$1450 REPORT BY TOLLEF WINSLOW file://C:\Documents and Settings\EpochAdmin\My Documents\My Wells\ENI\20100924.htm Daily Report ENI Petroleum DAILY WELLSITE REPORT 1 EPOCH 01 11-01 REPORT FOR KEENER/GOERLICH DATE Sep 28,2010 DEPTH 3719' PRESENT OPERATION DRILLING AHEAD TIME 00:52:53 YESTERDAY 2347' 24 HOUR FOOTAGE 1372' CASING INFORMATION 20"@ 160' 13 3/8"@ 2334' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 3646.95' 68.35 340.55 2831.45' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 12 1/4" HYCALOG MSX619SA2C 226208 6x16 2347' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 329.6 @ 3242 6.8 @ 2854 147.5 114.68907 FT/HR SURFACE TORQUE 11972 @ 2788 39 @ 2347 2954.7 0.00000 AMPS WEIGHT ON BIT 28 @ 2367 -5 @ 3705 7.8 1.82926 KLBS ROTARY RPM 143 @ 3078 0 @ 2347 54.8 0.00000 RPM PUMP PRESSURE 1511 @ 3705 580 @ 2447 1220.6 1099.28284 PSI DRILLING MUD REPORT DEPTH 3430/2840 MW 8.9 VIS 53 PV 12 YP 29 FL 7 Gels 12/18/20 CL- 750 FC 1/ SOL 3 SD 0.1 OIL 2/95 MBL 6 pH 9.7 Ca+ 60 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 62 @ 2811 0 @ 2393.00000 17.6 TRIP GAS 0 CUTTING GAS 0 @ 3719 0 @ 3719.00000 0.0 WIPER GAS 0 CHROMATOGRAPHY(ppm) SURVEY 0 METHANE(C-1) 13183 @ 2811 44 © 2393 3438.5 CONNECTION GAS HIGH 0 ETHANE(C-2) 0 @ 3719 0 @ 3719 0.0 AVG 17 PROPANE(C-3) 0 @ 3719 0 @ 3719 0.0 CURRENT 26 BUTANE(C-4) 0 @ 3719 0 @ 3719 0.0 CURRENT BACKGROUND/AVG 25 1 PENTANE(C-5) 0 @ 3719 0 @ 3719 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION SAND=MEDIUM LIGHT GRAY TO MEDIUM GRAY TO MEDIUM DARK GRAY WITH A SALT AND PEPPER APPEARANCE AT BEGINNING OF INTERVAL;LOWER MEDIUM TO UPPER FINE WITH OCCASIONAL LOWER FINE GRAINS;SPHERICAL TO SUB-DISCOIDAL; LITHOLOGY ANGULAR TO SUB-ROUNDED;MODERATELY SORTED;UNCONSOLIDATED SAND;GRAIN SUPPORTED;TEXTURALLY IMMATURE; COMPOSITIONALLY IMMATURE;TRANSLUCENT AND MILKY WHITE QUARTZ;ACCESSORIES INCLUDE:LIGHT GREEN GLAUCONITIC, BLACK CHERT AND PALE YELLOWISH ORANGE LITHICS;SMALL AMOUNTS OF LIGHT GRAY CLAY WITH ENTRAINED SAND; POROSITY AND PERMEABILITY VISUALLY GOOD;NO OIL. PRESENT L THOLOGY SAND 90%,CLAY 10 DAILY ACTIVITY ROTARY DRILL 20'NEW HOLE FROM 2347'TO 2367';DISPLACE SPUD MUD TO LSND MUD(8.8+MW);PERFORM LEAK OFF SUMMARY TEST;TEST RESULTS 12.1 EMW;ROTARY DRILL FROM 2367'TO 3719'. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML$3045, RIGWATCH$1450 REPORT BY TOLLEF WINSLOW file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY ... Daily Report ENI Petroleum DAILY WELLSITE REPORT U EPOCH OI 11-01 REPORT FOR KEENER/GOERLICH DATE Sep 28,2010 DEPTH 4711' PRESENT OPERATION POOH TIME 24:00:00 YESTERDAY 3719' 24 HOUR FOOTAGE 992' CASING INFORMATION 20"@ 160' 13 3/8"@ 2334' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 4606.08' 68.96 340.37 2628.89' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 12 1/4" HYCALOG MSX619SA2C 226208 6 x 16 2347' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 383.6 @ 3907 0.6 @ 4621 174.1 3.42560 FT/HR SURFACE TORQUE 0 @ 4710 0 @ 4710 0.0 0.00000 AMPS WEIGHT ON BIT 35 @ 4638 -1 @ 3818 8.1 30.22730 KLBS ROTARY RPM 0 @ 4710 0 @ 4710 0.0 0.00000 RPM PUMP PRESSURE 1720 @ 4364 862 @ 4009 1552.5 1670.71643 PSI DRILLING MUD REPORT DEPTH MW 8.9 VIS 91 PV 12 YP 30 FL 5.8 Gels 12/21/24 CL- 1050 FC 1/ SOL 4.5 SD 0.1 OIL 2/94 MBL 9.5 pH 9.9 Ca+ 40 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 52 @ 3799 0 @ 3852 13.1 TRIP GAS 0 CUTTING GAS @ @ WIPER GAS 0 CHROMATOGRAPHY(ppm) SURVEY 0 METHANE(C-1) 10684 @ 3799 44 @ 3852 2622.2 CONNECTION GAS HIGH 0 ETHANE(C-2) @ @ AVG 13 PROPANE(C-3) @ @ CURRENT 0 BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG 0 PENTANE(C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION SAND/CONGLOMERATIC SAND=DARK GRAY TO GRAYISH BLACK;UPPER VERY COARSE TO LOWER MEDIUM,PREDOMINATELY UPPER TO LOWER COARSE;SPHERICAL TO SUB-DISCOIDAL;SUB-ROUNDED TO ROUNDED CHERT,ANGULAR TO SUB-ANGULAR QUARTZ;POORLY SORTED;UNCONSOLIDATED SAND,CONSOLIDATED SANDSTONE;SILICEOUS CEMENT;GRAIN SUPPORTED AND MATRIX/CEMENT SUPPORTED QUARTZ SANDSTONE;TEXTURALLY IMMATURE;COMPOSITIONALLY IMMATURE;GRAYISH BLACK TO LITHOLOGY GRAY AND BLUISH GREEN CHERT,CHERT IS BOTH ANGULAR AND ROUNDED,ANGULAR CHERT HAS CONCOIDAL FRACTURES; TRANSLUCENT AND MILKY WHITE QUARTZ;QUARTZ SAND ALSO CONTAINS DISSEMINATED AND GRAIN ENCRUSTED PYRITE, BLACK CARBONACEOUS MATERIAL AND BLACK CHERT;QUARTZ SAND EXHIBITS LIGHT,10%FAINT BROWN STAIN;VERY FAINT DARK BROWN FLUORESCENCE CUT;CLEAR CUT NO RESIDUAL CUT;NO RESIDUAL FLUORESCENCE CUT NO OIL ODOR;POROSITY AND PERMEABILITY VISUALLY POOR. PRESENT SAND 100% LITHOLOGY DAILY ACTIVITY SUMMARY ROTARY DRILL FROM 3719'TO 4711';TRIP OUT OF HOLE DUE TO POOR ROP,POOH AT 3380'AT MIDNIGHT. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML$3045, RIGWATCH$1450 REPORT BY TOLLEF WINSLOW file://C:\Documents and Settings\EpochAdmin\My Documents\My Wells\ENI\OI11-0... OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent p folder to view it in digital format.